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Home My WebLink About207-055m Pr~o°ect Well Histo File Co~r Pa e I age ~ ~y g XHVZE This page identifies those items that were not scanned during the initial produetion scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q ~ - ~~S Well History File Identifier Organizing (done) Two-sided II ( II'I I) I) II I II III ^ Rescan Needed II ~ IIII II ~ I I~II III RES AN DIG TAL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: p Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ D /s/ Project Proo~ng II ( I I II I I I~ I I) ( I II I BY: Maria Date: ~/3 ~~ ~~ /s/ ~ Scanning Preparation BY: c' x30= ~ Date: ~ Production Scanning + = TOTAL PAGES ~ ~ oes not include cover shee1 ~co~nt d /s/ Stage 1 Page Count from Scanned File: ~(Count does include cov sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: J?' QG~ lsl ~M,~ ~ ~ -~r Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: ~S~ Scanning is complete at this point unless rescanning is required. II ~ II ~I I~ ~(I ~ I~(~I ReScanned II I II II II (I III (('ll BY: Maria Date: ~S~ Comments about this file: Quality Checked (II IIIII~ I~I IIII (I~ 10/6/2005 Well History File Cover Page.doc ~- .~ ~ ,. ~~ _ ~ ~w °~ ~ 2t ~~ ~, W ' a~-" x ~ ; ~~ ' ~ " ~' MICROFILMED 6/30/2010 DO .NOT PLACE ANY NEW MATERIAL UNDER-THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc STATE OF ALASKA ~` '%A~A AND GAS CONSERVATION COMMISS! REPO,~r,,oF, SUNDRY WELL OPERATIONS t. operations Pertormed: an on ~ pair w ell Plug Perforations J" Stirrwlate "` Other ~" Install Gas Lift . , ... „ `~6 Completion Alter Casing ~- Pull Tubing ~` Perforate New Pbol ~ Waiver ~ Time Extension Change Approved Program Operat. Shutdown ~"' Perforate J" Re-enter Suspended Well 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~' Exploratory "" 207-055 3. Address: Stratigraphic Service .API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23356-60 7. Property~signajion: ~ 8. Well Name and Number: ADL 25660, 25661, 25663 ~' 1J-158L1 9. Field/Pool(s): ~ Kuparuk River Field /West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 12261 feet Plugs (measured) None true vertical 3236 feet Junk (measured) None Effective Depth measured 12251 feet Packer (measured) 0 true vertical 3236 feet (true vertucal) 0 Casing Length Size MD ND Burst Collapse CONDUCTOR 80 20 121 121 SURFACE 3350 10.75 3395 2153 PRODUCTION 7850 7.625 7890 3323 D LINER SLOTS 4611 4.5 12251 3236 Perforation depth: Measured depth: 7702'-8608', 8908'-9892', 11216'-12206' True Vertical Depth: 3258'-3227, 3257-3243', 3242'-3235' .,. ~~~,,, ~ ~.~.( fp ;; ~~1~i f 14 P E' fl:v S S 1b 1.% Tubing (size, grade, MD, and TVD) 3.5, L-80, 7337 MD, 3232 TVD Packers & SSSV (type, MD, and TVD) no packer Camco DS nipple @ 485' MD and 485' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation si Subsequent to operation si 13. Attachments .Well Class after proposed work: Copies of Logs and'Surveys run Exploratory " Development Service . Well Status after work: Oil Gas WDSPL Daily Report of Well Operations XXX GSTOR I'-'" WAG " GASINJ r WINJ ~ SPLUG '° 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact Brett Packer ~ 265-6845 Printed Name Brett Packer Title Wells Engineer Signature % c~_ ~ "" Phone: 265-6845 Date ~ /~ 7/ ` ~ ~ / 'L.~ /~T RBDMS MAR ~ 4 20'~ ~ ~, ~ ~ 'Z ~ -/" Form 10-404 Revised 7/2009 '~~'~' ~/~~~ Submit Original Only l - KUP - 1J-158L1 f ~ORUC0~11~~1~5 ~'l Well Attributes ~^ _ Max Angle & MD TD \ y F ) Wellbore APVU WI '. Fieltl Name I Well Statu I icl !'I MD (ftK6) Acl Btm (ftKB) -' ~ SU(129~ss5660 WEST SAK PROD 95.95 ~ 11.273.52 12261.0 C ent H2s ly pri) (Dale Annolation IEnd Date KB-Grd (ft) Rig Release Date ,,,. Weu conrg; Mnnple La:erp!s,:u tsal -.SSSV. NIPPLE 'll 7/10/2009 Last WO: 4301 6/21/2007 .: :, a "s _. Scherne9 A1ual A notation Depth (flK8) IEnd Dale ~hon ~L tMOd ... Entl Date Last lag Rev Reason WORKOVER ImoSbor 3i 112010 Casing Stnnnnn~s -- _ _ HANGER 36 ~ 9`~ Cas ng Des pt 51 g O Slr y ID .. Top (ftKB) Set D pth (f Set D pth (ND) . Str ng Wt.-. Str g SL ing Top Thrd D SAND I (ANGER 4 1 1 U.i / 44C1 0 7 6749 3 259.8 11 60 L fl0 BTC . 1 ID To kK8 Set De th f ._ Set De Ih ND SU n Wt... Str ------ - - - Casing Des nphon .String O. Sv y Pl I P (~ P ( ) 9 9 ~ Siring TOP Thrd U LINER SLO I S 4 12 1 n / 653.2 12 251 l7 3,23G.2 11 60 L fl0 BTC L r ;Alai:. ~ - - 'Perforations 8 Slots --- - - - -- ___- _- ) snot - Top (TVD) Btm (1"VDi 'Dens I Top (HKB) Bim (ftK6)I (ftKe) IIINEi Zone Date (sh'~' Type Comment 7,702 8 608 3,258.3 3,~fi.9 WS D, 1J-158L7 16116/2007 32.0 SLOTS Alt SLOT/BLANK, 25" long z .125" @ 4 circumi rows, staggeretl 18 deg. -"~ 8,908 9.892 3,256.8 3.245 4 WS D, 1J-t 58U 6!16/2007 32.0 SLOTS Alt SLOT/BLANK, 25" long x .125" @ coNDUC7oR. 4 circumi rows, staggeretl 18 deg. a,-, z, NIPPLE. asS 11,216 1220G 3,242.0 723'1.'. WS D, 1J-158L7 6/16/2007 32.0 SLOTS AIt SLOTlBLANK, 2.5"long x.125"@ _ 4 circumi rows, staggered 18 deg. ,I ___ Hea,Tmce, 4, ~''Notes:General 8 Safety ._ .._ - __ TUBING, 2,997 End Date Annotation 6/21/2007 '.NOTE:MULTI-Lf II I:AL WELL:IJ-158 (B-SANO). 1J-i58L1 (D-SAND) 8!21/2008 NOTE VIEW SCFiB Ip,TIC w/Alaska Schematic9.0 3/1/2010 NOTE WORKOVLR /27/2010 CONVERSION FROM ESP TO GAS LIFT SURFACE, 45-3,395 GAS LIFT, _ 4,937 GAS LIFT, 7,178 NIPPLE. 7.222 GAUGE, 7,272 LOCATOR, 7,309 SEA1 ASSY, SLOTS 7,782-8,688 _ -- SLOTS, _ 8,988-9,892 _ ~ ~"^b. °0°r° Y SLOTS. 11 2,6-,2 286 111jjj , , ~ ~ D LINER SLOTS. 7.653-12,261 ro(u-ufiu>. , 2.261 1 2 Inc 1°1 Valve Latoh Size TRO Run Gom... ~J-158 Pre and Post Rig Events DATE SUMMARY 12/3/09 PRE RWO T-POT (PASSED ), T-PPPOT (PASSED ), UT-POT (.PASSED ), UT-PPPOT PASSED ), LT-POT (FAILED ), LT-PPPOT (FAILED ), IC-POT (PASSED ), IC- PPPOT .PASSED ), FT-LDS ALL NORMAL. 1/4/10 MEASURED SBHP @ 7150' SLM (1674 psi ). GRADIENT @ 1300' SLM (977 psi) & GRADIENT @ 100' SLM(545 psi ). COMPLETE. 1/24/10 BULLHEADED 90 BBL OF DIESEL DOWN THE IA AT 2 BPM. PUMP PRESSURE GRADUALLY INCREASED FROM 750 PSI TO 1000 PSI, SHUT IN THE IA. BULLHEADED 50 BBL OF DIESEL DOWN THE TUBING AT 2 BPM. PUMP PRESSURE GRADUALLY INCREASED FROM 950 PSI TO 1075 PSI. 1/28/10 BLEED T & IA , 30 MIN EACH VERIFIED FLUIDS TO SURFACE. 3/3/10 PULLED B&R f/ RHC @ 7221' RKB. DETERMINED ORIENTATION OF GLM #2 POCKET @ 3:00 LOOKING DH. PULLED VALVES @ 4936' & 7177 RKB. ATTEMPTED SET GLVs @ SAME, POOR ACTION & THICK FLUID. IN PROGRESS. 3/4/10 DISPLACED TBG WITH D$L. SET 5/16" OV @ 717T, GLV @ 4936' RKB. PULLED RHC BODY @ 7221' RKB. COMPLETE. ConocoPhillips Time Log & Summary Wellview Web Reparting~~ ~O Well Name: 1J-158 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 211 0/201 0 2:00:00 AM Rig Release: 2/27/2010 4:30:00 PM Time Lo s "Date From To Dur S. De th E. De th Phase Code Subcode T Comment 2/10/2010 2a hr Summary Completed 1J 135 program. Move Nordic Rig 3 off of 1J 135. 00:00 01:00 1.00 COMPZ -MOVE MOB P Move Nordic Rig 3 off of 1J 135 Well Slot. Move Rig over the skid for the 13 5/8" BOP Stack. Accept Nordic Ri 3 at 02:00 hours, 02/10/2010. 01:00 05:00 4.00 COMPZ MOVE MOB P Nipple down 13 5/8" Stack from stump on rig and set on skid. Mover over the skid with the 11" BOP Stack. Pick up 11"Stack and set on ri stum . 05:00 08:00 3.00 COMPZ MOVE MOB P Back Rig off of the 11" BOP skid and spot in front of 1J 158 Well slot. Lay double mats and continue to prep Well Slot. S of ri over well. 08:00 13:30 5.50 COMPZ RPEOPI RURD P Spot equip. RU hardlines. RU cellar hoses & load its. 13:30 15:00 1.50 COMPZ WELCTL KLWL P RU lubricator. Pull BPV. Pressures IA 300 psi Tubing 350 psi. OA 20 si. 15:00 17:00 2.00 COMPZ WELCTL KLWL P Start pumping down tubing taking returns from IA to kill tank. Pump 4 BPM w/ 300 psi pump pressure, 350 psi IA pressure. Pumped 310 bbls shut down, guage kill tank and take pressures. Kill tank had 127 bbls. SITP 150 psi, IA 160 psi. Pumped another 75 bbls and returns were 8.6# all SW. SD blow down lines. 17:00 18:30 1.50 COMPZ WELCTL P Bullhead 110 bbls. down the Tubing at 4.0 b m/340 si. 18:30 21:00 2.50 COMPZ WELCTL P Monitor Well and attempt to read stabilized SITP. Un-load pellets of salt. 21:00 22:00 1.00 COMPZ WELCTL P Thaw out line going to Tiger Tank. 22:00 00:00 2.00 COMPZ WELCTL P Circulate Well down the Tubing at 2.5 bpm/160 psi. Take returns to Rig Pits. Gas to surface. Route returns to Tiger Tank. Discuss plan forward with Anchorage Engineer to plan on wei htin u . 2/11 /2010 Circulate and kill Well w/9.8 ppg Brine, Set BPV and Blanking Plug. ND Tree. Daily Fluid Loss = 356 bbls, Cum Fluid Loss = 445 bbls Page 1 of 16 Time Lo s :Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 07:30 7.50 COMPZ WELCTI CIRC P Finish circulating Well. Shut in and monitor. SITP = 120 psi and stable. IA also 120 psi. Calculate kill weight fluid at 9.23 ppg. Order out Vac Truck from Mi with 9.6 ppg Brine. . Build fluid in rig Pits from 8.6 ppg up to 9.6 07:30 10:00 2.50 COMPZ WELCTL CIRC P Line up to circulate well over to 9.6 ppg Brine. ICP 250 @ 4 BPM. Pumped 345 bbls 9. ppg brine until returns of 9.6 ppg. SI blow down lines Check well for pressure. Bled pressure to 0 psi and small flow back to gas buster. Flowed back 8 bbls in 45 min. well dead. 10:00 12:00 2.00 COMPZ WELCTL NUND P Blow down lines and ND cellar lines. O en tubin well flowin a ain. 12:00 14:30 2.50 COMPZ WELCTL KLWL P Continue to monitor well. Bled off IA, and tbg. SI to monitor pressures while wt u its to 9.8 14:30 18:00. 3.50 COMPZ WELCTL KLWL P RU circulating lines and PT to 2500. Pumped 108 bbls down tubing lost 104 bbls. Switched and pumped 181 bbls down IA lost 34 bbls. 4 BPM w/180 psi. SI monitor well. Static. Total losses for the da 356 bbls. 18:00 20:00 2.00 COMPZ WELCTL MPSP P Attempt to set BPV. However tubing side has slight flow. Allow Tubing and IA to U-Tube. Monitor. Pump 20 bbls of 9.8 ppg down Tubing. Set BPV. 20:00 20:30 0.50 COMPZ WELCTL SFTY P PJSM. Nipple down Production Tree. Discussed hand and body placement, use of proper tools, overhead loads. 20:30 23:30 3.00 COMPZ WELCTI NUND P Nipple down Production Tree and remove Bonnet. 23:30 00:00 0.50 COMPZ WELCTI NUND P Begin to Nipple up 11" BOP Stack. 2/12/2010 Test BOPE at 250/5,000 psi. Pull BP/BPV. Pull Tubing Hanger free. Pump hot 9.8 ppg Brine down IA. Lay down Tubin Han er. Dail fluid loss = 145 bbls. Cum loss = 590 bbls. 00:00 09:30 9.50 COMPZ WELCTL NUND P Finish nipple up XO Flange. and BOP Stack. Install 2 3/8" Pipe Rams ih top section. Install Riser. Normally have 4 men in cellar to NU & ND, only 3 now because of present crew count. 09:30 16:00 6.50 COMPZ WELCTL BOPE P Test 11" BOPE 250/5000 /annular 250/3500 psi. Witnessing of test waived b Chuck Scheive 2-9-2010. 16:00 18:00 2.00 COMPZ WELCTI NUND P BD test equip. MU retrieving tool, pulled test plug, pulled BPV. MU Xover onsafe valve. MU landin 't. Page 2 of 16 Time Lo s .Date From To Dur S. De th E De th Phase Code Subcode T Comment 18:00 20:00 2.00 COMPZ RPCOM THGR P Back out lock down screws. Attempt to pull Tubing Hanger free with 210K. Rig up and apply steam heat to Wellhead. Pulled Tubing Hanger free with 160K. Pulled- Tubin Han er to floor with 105K. 20:00 21:30 1.50 COMPZ RPCOM CIRC P Pumped 190 bbls of hot 9.8 ppg Brine down IA at 4.0 b m/140 si: 21:30 22:00 0.50 COMPZ RPCOM OWFF P Flow check Well. Observe slight flow from IA. Flow stopped. Observe slow fluid dro . 22:00 22:30 0.50 COMPZ RPCOM SFTY P PJSM to lay down Tubing Hanger and RU to lay down 4 1/2" ESP Completion. Discussed pinch oints, work area, sus ended loads. 22:30 00:00 1.50 COMPZ RPCOM PULD P Start to lay down Tubing Hanger and Landing Joint. Hydraulic hose burst going to Top Drive. Remove hose and safe out. Clean up work area on Floor. Finish laying down Tubing Hanger and Landing Joint. (inspected Hanger and found damaged and flatten threads . Approximately a -2" wide section inside BPV profile. Damage most likely caused from repeated CT, S-Line, and E-Lines runs in and out of Well. 2/13/2010 Single down 4 1/2" ESP Completion. Lay down ESP Assembly. Daily Fluid Loss = 33 bbls. Cum Loss = 623 bbls. 00:00 21:30 21.50 7,231 0 COMPZ RPCOM PULL P Pull and single down 4 1/2", 12.6 Ib/ft, L-80, IBTM Tubing while spooling ESP Cable. Shut down, strap and unload pipe shed after .each row. Lay down a total of a Tubing Hanger on a full Joint , 230 Joints of Tubing, and 1 ea GLM Assembly. Recovered 3 ea Protectolizers, 2 ea Flat Guards, and 12 ea Stainless Steel Bands. (Note: left 3 ea SS Bands in hole. Discussed the +/- of making a separate fishing trip to attempt recovery of the lost bands with Anchorage Engineer. Decision made to continue with next step in planned ro ram 21:30 00:00 2.50 COMPZ RPCOM PULD P ESP Assembly at surface. Break down, inspect, and lay down ESP sections per Centrilift Service Rep. Motor burnt. 2/14/2010 Make-up Clean Out BHA. Single in with 3 1/2" Drill Plpe. Found possible sand or junk at 7,563-ft. Unable to make an further hole. Start TOH. Dail Fluid Loss = 353 bbls. Cum Loss = 976 bbls Page 3 of 16 ':Time. Lo s -.Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 -05:30 5.50 0 COMPZ RPCOM RURD P Clear and Clean Rig Floor. Load out ESP sections in shipping boxes. Re-count ESP Clamps and clear Pipe Shed. Rig up to handle BHA and 3 1/2" Drill Pipe. Install Wear Bushing. Bring 3 1/2" Tubing and remainder of BHA needed into Pipe Shed. Tall same. 05:30 14:00 8.50 5,322 5,322 COMPZ RPEQPI PULD P Make-up Clean Out BHA. RIH on 3 1/2' Drill Pipe, PU from pipe shed to 5,322'. 14:00 15:30 1.50 5,322 5,322 COMPZ RPCOM OTHR P Shut down, secured well. PJSM w/crane operator. Remove ESP cable and spooler from rig floor while crane was availble. 15:30 19:30 4.00 5,322 7,563 COMPZ RPEQPI PULD P Continue to PU 3 1/2" drill pipe and RIH from 5,322' to 7367. Up wt 120K Dwn wt 45K, Est. circulation w/3 BPM @ 675 psi. Continue RIH with no problems down to 7,563-ft., which is 10-ft above the Seal Bore Receptacle. Tagged up. Attempt to make further hole. Increase pump rate to 4.0 bpm/1,100 psi: Pull up -hole. RIH and tagged up at 7,559-ft. Lost hole. Tried once again to make hole. No joy. Pulled up hole and tried to work back down. Lost 30 more feet. Now at ~ 7,529-ft. Had 8K over pull. Lay down 2 Joints. Discussed plan forward with Anchorage Engineer. (decision made to POOH and run the 2 3/8" x 3 1/2" clean out strin 19:30 00:00 4.50 7,529 187 COMPZ RPEQPI TRIP P Drop Dart and open Pump Out Sub.. Blow down Top Drive. Trip out with 3 1/2" Drill Pipe standing back in Derrick. (loading Pipe Shed with 2 3/8" Drill Pi e. Tall same . 2/15/2010 Plck up 2 3/8" Clean Out String. Continue RIH with 3 1/2" Drill Plpe. Clean out to 7,625-ft. POOH, standing back 3 1!2" Drill Pipe. Lay down the 2 3/8" Drill Pipe. Lay down BHA #2. Daily Fluid Loss =345 bbls. Cum Loss = 1,321 bbls 00:00 04:30 4.50 187 0 COMPZ RPEQPI PULD P Lay down BHA #1 The last 20 feet of the BHA was plugged with formation sand. Clear sand from BHA. Rig down handling equipment. Clean Rig Floor. Finish loading Pipe shed with 2 3/8" PAC Drill Pi e. 04:30 08:30 •4.00 0 COMPZ RPEQPI TRIP P Rig up equipment to handle 2 3/8" PAC Drill Pipe. Make up 2 3/8" Mule Shoe. Single in with 53 jts of 2 3/8" PAC Drill Pi a from Pi a Shed. 08:30 12:00 3.50 COMPZ RPEQPI TRIP P Switch running tools over for 3 1/2" drill pipe. Start running drill pipe from derrick. Page 4 of 16 Time. Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 12:00 13:00 1.00 7,404 7,543 COMPZ RPEQPI WASH P With mule shoe @ 7404',Established circualtion w/ 40 bbls. 3 BPM, 810 psi. Lowered in hole to 7501',Closed bag and established reverse circulation 3 BPM @ 60 psi. Lowered pressure on bag and washed down to 7543' with no returns. Lost 111 bbls Burin this rocedure. 13:00 15:00 2.00 7,543 7,607 COMPZ RPEQPI WASH P SD pump, opened bag. Pumped conventional down tubing 4 BPM 1290 psi washing down to 7607'(12' below SBE). While working pipe up and down, pumped 40 bbl sweep 3# bbl Flowvisc Plus. Returns were only 50 to 60%. SD pump; lined up and pumped 70 bbls down tubing and annulus @ 46PM w/90 psi. FP 140 psi. SD pump. Pulled 5 studs to 7114'. Lost total of 216 bbls during clean out. 15:00 16:00 1.00 7,114 7,625 COMPZ RPEQPI OTHR P Monitor well for 30 min. let possible sand settle. Ran back in hole to 7625' no fill. 16:00 19:30 3.50 7,625 1,669 COMPZ RPEQPI TRIP P Trip out with 3 1/2" Drill Pipe standin back in Derrick. 19:30 22:00 2.50 1,669 0 COMPZ RPEQPI PULD P Change out handling equipment to handle 2 3/8" PAC Drill Pipe. Single down 2 3/8" Drill Pipe in Pipe Shed. La down BHA #2. 22:00 00:00 2.00 0 COMPZ RPEQPI PULD P Change out handling equipment to handle 3 1/2" Drill Pipe. Make up BHA #3 as follows: 4 1/2" Bull Nose Wash Nozzle, XO, 3 ea Joints of IBTM Tubing, XO, 1 ea 3 1/2" EUE 8rd Tubing, XO, 4 3/4" Lubricated Bumper Sub, 4 3/4" Oil Jar, 3 1/2" Pum Out Sub. 2/16/2010 RIH with BHA #3. Wash Sand Bridges from 7,345-ft down to top of SBR at 7,571-ft,dmd. Clean out sand from inside of SBR to "NO-GO at 7,593-ft. TOH with 3 1/2" Drill Pipe and lay down BHA #3. -Daily Fluid LOss = 365 bbls. Cum to Date = 1686 bbls. 00:00 04:00 4.00 0 7,345 COMPZ RPEQPI TRIP P Trip in with BHA #3 and 3 1/2".Drill Pipe from Derrick. PUW = 110K. SOW = 50K. Page5of16 Time: Lo s 'Date From To Dur S. De th E. De th Phase Code Subcode T Comment 04:00 06:30 2.50 7,345 7,575 COMPZ RPEQPI WASH P Continue RIH. Started taking weight at 7,345-ft. Set down at 7,361-ft. Bring pump on line at 2.0 bpm/680 psi. Wash down to 7,433-ft. PUH with normal string weight. Continue down to -7,500-ft. Had to increase pump rate to 2.5 bpm/1150 psi to get through sand bridges. Set down again at 7,571-ft, (top of Seal Bore Receptacle, Driller's measured depth). Made two more attempts to enter same. (decide to clean up sand above before continuing to enter SBR). PUH and set back 5 stands. Park Nozzle at 7,122-ft. Down squeeze IA at 4.0 bpm/120 psi. Volume pumped 70 bbls. Bring pump off line, slowly. Leave Well shut in with 40 psi and let pressure bleed off into "D" Lateral. 06:30 11:00 4.50 7,122 7,593 COMPZ RPEQPI WASH P Leave Well shut in for 2 hours. Open Well with an estimated 15 - 20 psi. Observe a slight flow then no flow. RIH with the 5 stands from the Derrick. Clear down to 7,575-ft (dry tag). Set down at same spot as before. Bring pump on line at 2.0 bpm/700 psi and attempt to enter the SBR. Also tried at 1.0 bpm/400 psi and at 3.0 bpm/1,330 psi. After several attempts at 3.0 bpm nozzle entered. Wash inside of SBR down to "NO-GO" at 7,593-ft. Pull out with a slight drag. Re-enter SBR with little difficulty. Clear down to "NO-GO". Pull back up to -7,113-ft. and ark nozzle. 11:00 14:00 3.00 7,113 7,593 COMPZ RPEQPI WASH P Down squeeze IA at 4.0 bpm/125 psi. Volume pumped, 70 bbls. Let set for 2 hrs with 70 psig Final shut in pressure. Open up well with 20 si .RIH with no fill to . 14:00 18:00 4.00 7,593 3,089 COMPZ RPEQPI TRIP P POOH slowly for the first 20 stands f/ 7,593' t/ 3,089' MD 18:00 19:30 1.50 3,089 3,089 COMPZ RIGMNT RGRP P Slip and Cut drill line (84-ft). Inspect Draw Works. 19:30 21:30 2.00 3,089 186 COMPZ RPEQPI TRIP P Continue to trip out with 3 1/2" Drill Pipe, standing back in Derrick. BHA #3 to surface. 21:30 22:30 1.00 186 0 COMPZ RPEQPI PULD P Lay down BHA #3. Inspect 4 1/2" Wash Nozzle. No marks. Clear and Clean Floor. 22:30 23:30 1.00 0 COMPZ RPEQPI PULD P Rig up Floor to handle LEM Assembly. Perform final LEM Assembt ins ection. 23:30 00:00 0.50 COMPZ RPEQPI SFTY P PJSM. Discuss using proper tools, hand and body placement, overhead loads. Page 6 of 16 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 2/17/2010 24 hr Summary Unable to enter Mainbore Lateral. It is assumed that the Mule Shoe is hanging up on the D-Sand Lateral Window. TOH. Lay down assemblies. Inspect Mule Shoe. MS shows signs of scars and scuff marks from attempting to work passed the Window. Make up Assemblies again. However Run #2 has a "bent joint" included 'ust above the Seal Assembl .Dail Fluid Loss = 164 bbls. Cum Fluid Loss = 1,850 bbls. 00:00 02:30 2.50 0 0 COMPZ RPEQPI PULD P Make up Seal Assembly and LEM Assembly. Make up ZXP Packer . Make up inner string, including MDW Tool. 02:30 03:00 0.50 0 293 COMPZ RPEQPI TRIP P RIH with one stand. Perform MWD Pulse Test. Good. 03:00 11:00 8.00 293 7,345 COMPZ RPEQPI TRIP P Trip in with LEM Assembly and 3 1/2" Drill Pi a from Derrick. 11:00 11:30 0.50 7,345 7,345 COMPZ RPEQPI OTHR P MU TD and Establish parameters 110k up wt, 55k do wt. PP @ 350 si 2 b m. 11:30 13:30 2.00 7,345 .7,450 COMPZ RPEQPI TRIP P RIH to 7,450' and Tag, Attempt to work down -changing oreintation multiple times -still unable to get ast 7,450' 13:30 14:00 0.50 7,450 7,450 COMPZ RPEQPI OTHR P Blow down top drive 14:00 19:30 5.50 7,450 294 COMPZ RPEQPI TRIP P POOH f/ 7,350' MD w/110k up wt. LEM Assembl at surface 19:30 21:00 1.50 294 0 COMPZ RPEQPI PULD P Lay down inner string including MWD: Lay down ZXP Assembly. Lay down LEM Assembly. (marked both DB Nipple Assemblies as to their proper running order before laying down). Lay down Seal Section. Inspect same. Found several scarred and scuffed areas on the side of the Mule Shoe. Also a few dings on the lip of the Mule Shoe wwere noticed. No evidence of any sand on the seals of the Seal Assembly or on any of the other com onents. 21:00 00:00 3.00 0 294 COMPZ RPEQPI PULD P Bring 4 1/2" 12.6 Ib/ft L-80 IBTM x ST-L XO Tubing Joint (bent Jt) into Pipe Shed and tally. Make up Seal Assembly on the 4 1/2" "bent" Joint. Pick-up LEM Assembly. Pick up ZXP Assembly. Make up inner string includin MWD Tool. 2/18/2010 RIH w/LEM Assy #2 on 3 1/2" Drill Pipe. Tagged up at 7,450-ft. Attempt to work down several times. No-joy. POOH. Lay down LEM Assy. Pick up Polish Mill BHA. and trip in with 3 1/2" Drill Pipe to 5,550-ft. Dail Fluid Loss = 243 bbls. Cum Fluid Loss = 2,093 bbls. 00:00 02:30 2.50 0 293 COMPZ RPEQPI TRIP P Make up and trip in with Lem Assembly on 3 1/2" Drill -Pipe from Derrick. 02:30 03:00 0.50 293 293 COMPZ RPEQPI OTHR P Shallow pulse test MWD -Good - Blow down To Drive. 03:00 11:00 8.00 293 7,345 COMPZ RPEQPI TRIP P RIH w/ LEM BHA #2 on 3 1/2 DP from 293' to 7,345' MD. Page 7 of 16 Time Lo s Date From _To Dur S De th E. De th Phase Code Subcode T Comment 11:00 11:30 0.50 7,345 7,345 COMPZ RPEQPI OTHR P Gather Parameters: 110k up wt, 55k do wt. Pump pressure @350 psig 2 b m. 11:30 13:30 2.00 7,345 7,450 COMPZ RPEQPI PACK P RIH to 7,450' -Tag up. Attempt to work down -changed orientation mutiple times and still not able to get thru. POOH to 7,350'. 13:30 14:00 0.50 7,350 7,350 COMPZ RPEQPI OTHR P Blow down top drive 14:00 18:00 4.00 7,350 295 COMPZ RPEQPI TRIP P POOH from 7,350' MD w/ 110k up wt. to LEM BHA #2 18:00 20:00 2.00 295 0 COMPZ RPEQPI PULD P Lay down LEM BHA #2. Inspect Mule Shoe on Seal Assembly. Same as before, scuffed, scared, and a few small nicks. 20:00 20:45 0.75 0 0 COMPZ RPEQPI PULD P Rig up floor and handling equipment to handle next BHA. 20:45 21:00 0.25 0 0 COMPZ RPEQPI SFTY P PJSM. Descussed next BHA components. Hand and finger lacement, communications. 21:00 22:00 1.00 0 221 COMPZ RPEQPI PULD P Make up BHA #5 as follows: 4 1/8" Bull Nose, XO Sub, XO Sub, 2 ea Jts 2 7/8" PAC Drill Collars, XO Sub, XO Sub, 4 5/8" String MITI. 1 ea Jt 2 7/8" PAC Drill Collar, XO Sub, 5 1/4" Stabilizer Mill, 1 Stand of 3 1/2" Drill Pipe, Bumper Sub, Oil Jar, Pump Out Sub. Total Len th = 221.48-ft. 22:00 00:00 2.00 221 5,550 COMPZ RPEQPI TRIP P Trip in with BHA #5 and 3 1/2" Drill Pipe from Derrick to 5,550-ft. PUW = 77K. SOW = 60K. 2/19/2010 Dress LEM Window. TOH and lay down Mill Assy. Perform Weekly BOP Test. Make up LEM Assembly w/MWD, Run #3. Dail Fluid Loss = 180 bbls. Cum Fluid Loss to Date = 2,273 bbls. 00:00 01:00 1.00 5,550 7,452 COMPZ RPEQPI TRIP P Continue to TI H. Establish parameters as follows: PUW = 100K, SOW = 77K, RTW = 85K, Torque = 3K with 30 RPMs. With no RPMs, ease on down through Hook Hanger and tag with the 4 5/8" String Mill at 7,452-ft kb. Page 8 of 16 .Time. Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 01:00 04:00 3.00 7,452 7,593 COMPZ RPEQPI MILL P Bring pump on line at 0.7 bpm/60 psi. RPMs = 30. Lightly polish past the LEM Window with the 4 5/8" String Mill with no problems in 3 minutes. Pull back through with 15K over pull. Re-polish down and back ream times 3. Now have 5K over pull. Re-polish and back ream times 3 again. Now have no over pull Make a final down/up pass with no RPMs. Good. Continue back down and tag the Window with the 5 1/4" Stabilizer Mill at same depth, 7,452-ft. Increase RPMs to 50 and dress past the Window with 5 - 8K torque in 15 minutes. Continue down to 7,460-ft with no torque. Back ream with rotation with 3 - 5K torque. Repeat four times with very minimal torque. Stop rotation. Make a final down/up pass with no RPMs. Good. Continue down to the NO-Go in the ', Seal Bore Receptacle at 7,593-ft with no roblems. 04:00 05:30 1.50 7,593 7,593 COMPZ RPEOPI TRIP P Pull 3 Stands and park Bull Nose above Hook Hanger. Shut down Pump and wait for -30 minutes to allow for any mill fillings or any possible sand to settle out. Ran back to NO-GO once again at 7,593-ft (no rotation/no pump) with no roblems 05:30 10:00 4.50 7,593 221 COMPZ RPEQPI TRIP P Trip out with 3 1/2" Drill Pipe from 7,593' MD 10:00 11:00 1.00 221 0 COMPZ RPEQPI PULD P Lay down milling BHA -Lower mill showed signs of milling and upper mill had good milling signs on the lower side and minimal on the top side. 11:00 12:00 1.00 0 0 COMPZ RPEQPI OTHR P Change out to 3 1/2 DP equipment and Pull wear rin . 12:00 21:00 9.00 0 0 COMPZ RPEQPI BOPE P Set test plug- and fill BOPE. Conduct weekly BOP test @ 250/2,500 psig. 24 hr notice was given @ 0725 hrs on 2-18-10 and Witness of test by AOGCC was waived by Lou Grimaldi @ 0805 hrs on 2-19-10. Good test. Rig down test equipment. Pull Test Plug. Set Wear Bushin . 21:00 21:15 0.25 0 0 COMPZ RPEQPI SFTY P PJSM. Picking up LEM Assembly. Discussed team work and good communications. Also discussed the resent weather conditions. 21:15 23:15 2.00 294 294 COMPZ RPCOM PULD P Pick up new Seal Assembly. Make up LEM Assembly. Make up ZXP Packer Assembly. Install inner strip , includin MWD Tool. Page 9 of 16 Time Lo s Date From To Dur S. De th E.` De th Phase Code Subcode T Comment 23:15 00:00 0.75 294 390 COMPZ RPEQPI PULD P Run one stand of 3 1/2" Drill Pipe from Derrick. Perform MWD pulse test. Good. 2/20/2010 Trip in w/LEM Assy on 3 1/2" Drill Pipe. Set and test LEM Assembly. Release Setting Tool and POOH. Lay down Setting Tool and Inner String w/MWD Tool. Rig up to pick up 2 3/8" x 3 1/2" Clean Out String. Make up 2 3/8" Mule Shoe and start picking up 2 3/8" Drill Pipe. Daily Fluid Loss = 324 bbls. Cum Fluid Loss = 2,597 bbls. 00:00 06:30 6.50 390 7,359 COMPZ RPEQPI TRIP P Trip in with LEM Assembly on 3 1/2" Drill Pipe from the Derrick from 7,359' MD. 06:30 12:00 5.50 7,359 7,585 COMPZ RPEQPI OTHR P Establish Parameters: 2.5 bpm 500 psig. RIH and Tag @.7,440' +/- Top of Hook hanger. PU and orient from 17 degrees LHS to 121 degrees RHS. Slack off thru .Hook hanger with no tag -Tagged up @ 7,577' MD w/mule shoe w/orient @ 48 degrees LHS, PU and SO -tag same - 110k up wt, 60k do wt. continue to work with 13k SO wt and work down to 7,581' MD. Not able to get past. PU and orient to 27 degrees LHS and work down from 7,577 - fell thru 7,582' -continue down fo 7,585' with mule shoe and latch LEM @ 7,441' MD -Orient moved from 27 degrees LHS to 4 degrees LHS. Un latch and relatch. -Returns dropped from 16% to 7%. 12:00 13:30 1.50 7,585 7,263 COMPZ RPEQPI PACK P Drop 1.75" OD Ball and chase with 36 bbls @ 2 bpm @ 400 psig and seat ball Pressure to 2,000 psig and activate puher tool and set ZXP packer @ 7,313' w/ top of setting sleeve @ 7,303' MD. Release Hydrualic running toot @ 3,300 psi. PT Inner annulus @ 2,500 psig for 5 minutes -good test. Putl setting tool from acker ass 7,303' to 7,263' 13:30 17:30 4.00 7,263 7,263 COMPZ RPEQPI OTHR T Suspend operations due to phase 3 weather. Standby with crews and monitor well until Roads and Pads cleared 1J access road. 17:30 20:30 3.00 7,263 31 COMPZ RPEQP ITRIP P POOH from 7,263'. Standing back 3 1/2" Drill Plpe in Derrick. PUW = 95K 20:30 21:30 1.00 31 0 COMPZ RPEQP I PULD P Setting Tools and inner string wlMWDTooI at surface. Lay down same. 21:30 22:15 0.75 0 0 COMPZ RPEQP I PULD P Clear and clean Floor. Rig up handling equipment to pickup 2 3/8" PAC Drill Pi e. 22:15 22:30 0.25 0 0 COMPZ RPEQP I SFTY P PJSM. Picking up 2 3/8" Drill Pipe. Discussed hand and body lacement. Overhead loads. Page 10 of 16 Time Lo s Date From To Dur S: De th E. De th Phase Code Subcode T Comment 22:30 00:00 1.50 0 675 COMPZ RPEQPI PUTS P Make up 2 3/8" Mule Shoe. Pick up 2 3/8" PAC Drill Pipe from Pipe Shed. 2/21 /2010 RIH with 2 3/8" x 3 1/2" Clean Out String to 12,250'. Pump 2 ea 20 bbls Hi-Vis Sweeps and attempted to chase to surface. Fluid loss at 2.5 bpm. Start to lay down 3 1/2" Drill Pipe. Daily Fluid Loss - 747 bbls. Cum Fluid Loss to Date = 3,344 bbls. 00:00 03:30 3.50 675 5,265 COMPZ RPEQPI PUTS P Continue to single in with 2 3/8" Drill Pipe from Pipe Shed (total 164 jts). Sto to chan a handlin a ui ment. 03:30 04:00 0.50 5,265 5,265 COMPZ RPEQPI OTHR P Rig up to handle 3 1/2" Drill Pipe. 04:00 06:00 2.00 5,265 7,806 COMPZ RPEQPI TRIP P Continue RIH with clean out string. Pick up XO, Bumper Sub, and Oil Jars. Begin tripping in with 3 1/2" Drill Pi a from Derrick 7,806'. 06:00 06:30 0.50 7,806 7,806 COMPZ RPEQPI CIRC P Fill Drill pipe @ 3 bpm @ 2,200 psig w/ 24 bbls rior to RIH. 06:30 07:30 1.00 7,806 8,506 COMPZ RPEQPI TRIP P Continue to RIH with drill pipe from derrick from 7,806' to 8,506' and be in takin wt. 07:30 08:00 0.50 8,506 8,506 COMPZ RPEQPI OTHR P Gather Parameters: 1,700 psi @ 3 b m, 2k free for ue 15 m. 08:00 12:00 4.00 8,506 10,229 COMPZ RPEQPI FCO P Continuie to Clean out fill from 8,506' to 10,229' and ran out of down wt. POOH w/ 4 stds to 9,842' and add 3 stds of 4 3/4" OD DC's. to 10,119' MD. 12:00 18:00 6.00 10,229 12,250 COMPZ RPEQPI FCO P Continuie to Clean out fill from 10,229' MD. to 12,250' MD. 18:00 20:30 2.50 12,250 12,250 COMPZ RPEQPI CIRC P Pump 1-20 bbl 776 Lube sweep and chase with 70 bbls and pump a second 20 bbl 776 sweep. Pump rate 4.0 bpm/3,100 psi. Return rate -1.5 bpm. Loss rate 2.5 bpm. Total bbls pumped 612. No sign of either Sweep. End B-Sand Lateral clean out. Blow down To Drive. 20:30 00:00 3.50 12,250 10,456 COMPZ RPEQPI PUTB P Monitor-Well. Begin to single down 3 1/2" Drill Pipe to Pipe Shed. Lay down 10 joints. Stop to flow check Well. Continue to single down 3 1/2" Drill Pipe. Clear 3 1/2" Drill Pipe from Pi e. Shed as needed. 2/22/2010 Complete laying down 3 1/2" and 2 3/8" Drill Pipe. Daily fluid Loss = 349 bbls. Cum Fluid Loss = 3,693 bbls. 00:00 05:00 5.00 10,456 7,355 COMPZ RPEQPI PUTB P Continue to single down 3 1/2" Drill Pipe. Lay down 9 ea 4 3/4" Drill Collars. Resume laying down 3 1/2" Drill Pipe. Clear Pipe Shed as needed. (Also continue to load Pipe Shed with 31/2" Com letion Tubin Page 11 of 16 • Time Lo s `Date From To Dur S. De th E. De th` Phase Code Subcode T Comment 05:00 07:00 2.00 7,355 7,355 COMPZ RPEQPI CIRC P Park Mule Shoe at 7,355-ft. Rig up to Reverse Circulate. Pump 20 bbl 776 tube pill and Reverse Circulate 312 bbls at 3.0 bpm/60 psi. "Weak" returns to surface. SI annulus and flush DP w/ 40 bbls @ 1,710 psig. SI DP w/ 80 si . 07:00 12:00 5.00 7,355 7,355 COMPZ RPEQPI OWFF P Monitor SIWP for equalization. Bleed down from 80 psig to 10 psig. -Open up well and observe on trip tank - 10 bbl gain. Continue to Load 3 1/2 Completion string in pipe shed while waiting for well toe ualize. 12:00 14:30 2.50 7,355 5,322 COMPZ RPEQPI PULD P POOH laying down 3 1/2 DP f/ 7,355' to 5,322' w/ 58k u wt. 14:30 15:00 0.50 5,322 5,810 COMPZ RPEOPI TRIP P RIH with DP from derrick from 5,322' to 5,810' 15:00 15:30 0.50 5,810 5,810 COMPZ RPEQPI SFTY P Held PJSM on slipping and cutting drill line along with draw works ins ection. 15:30 16:30 1.00 5,810 5,810 COMPZ RPEQPI RGRP P Slip and cut 84' of drill line and ins ect draw works. 16:30 17:00 0.50 5,810 5,485 COMPZ RPEQPI PULD P POOH laying down 3 1/2 DP from 5,810' to 5,485'. 17:00 18:00 1.00 5,485 5,485 COMPZ RPEQPI OWFF T Standby with crews and monitor well waitin for Phase 3 weather to clear. 18:00 00:00 6.00 5,485 445 COMPZ RPEQPI PULD P Continue to POOH with the remaining 3 1/2 Drill Pipe. Pump Out Sub, Oil Jars, Lubricated Bumper Sub, X-O and 164 Jts of 2 3/8 PH-6 H dril Tubin . 2/23/2010 Continue POOH, lay down shoe. RU & Run 3 1/2" Completion string with tech wire & heat trace. Total fluid loss for the da = 26 BBLS. Cum Fluid Loss = 3,719 bbls. 00:00 01:00 1.00 445 0 COMPZ RPEQPI PUTS P Completed laying down 2 3/8" PAC Drill Pi a in Pi a Shed. 01:00 11:00 10.00 0 0 COMPZ RPCOM OTHR P Pull Wear Bushing. Clear and Clean Floor. Rig up Floor to handle 3 1/2" Completion Equipment and Tubing. Load all Completion equipment, Cannon Clamps and spot Iwire and Heat traces ools. 11:00 13:00 2.00 0 165 COMPZ RPCOM PULD P Break down seal assy x 4 1/2" IBTx 3 1/2 8rd cross over. PU and MU seal assy on 1 jt of 4 1/2" IBT Tubing and RIH. MU 4 1/2" IBT x EUE 8rd cross over pup jts on Gaurdian Gauge carrier and RIH. Tie in I-Tec wire and hang sheave. MU 4 1/2" IBTx 3 1/2 8rd cross over and 10' x 3 1/2" EUE 8rd Pup joint and RIH to 165' MD. 13:00 20:00 7.00 165 4,341 COMPZ RPCOM RCST P Begin Picking up and RIH w/ 3 1/2", 9.3#, L-80 EUE 8rd Tubing, installing Cannon X-Cplg clamps on every connection from 165' MD to 4341'. Page 12 of 16 • .Time Lo s .Date From To Dur S. De th E. De th Phase Code Subcode T Comment 20:00 00:00 4.00 4,341 5,132 COMPZ RPCOM RCST P Continue run 3 1/2" completion string picking up Heat trace, installing Cannon X-Cplg clamps. Observed - fluid loss at 26 BBLS for the day. UP WT - 160K SO WT - 150K 2/24/2010 Continue run 3 1/2" completion string from 5132' to 7338. Space out installing pup.Attempted to test lower seals on hanger -failed. Install BPV. ND 11" BOP stack. Notified AOGCC of upcoming ops. Total fluid loss for the da = 44 BBLS. Cum Fluid Loss = 3,763 bbls. 00:00 08:00 8.00 5,132 7,265 COMPZ RPCOM PULD P Continue run 3 1/2" completion string with Heat trace, installing Cannon X-Cplg clamps, from 5132' - 7,265'. U P WT - 75K SO WT - 50K 08:00 09:30 1.50 7,265 7,341 COMPZ RPCOM HOSO P RIH f/ 7,264' to 7,322' see seals start into SBE @ 16' in on jt 227 and NoGo'd out @ 7,314' w/ 3' in on jt 228 w/mule shoe @ 7,340.62'. POOH and lay down 3 jts. MU landing joint to Hanger and joint, MU X-O and 2' Spae out pup joint. Mu to string and finish installing Cannon clam s u to 2' Pu 'oint. 09:30 13:30 4.00 7,304 7,304 COMPZ RPCOM OTHR P Install Penetrators and Make final splice in Heat trace and I-tec wire. Gauge reading after 1,600 psig @ 63.8° F. 13:30 14:00 0.50 7,304 7,304 COMPZ RPCOM CIRC P Pump 25 bbls 9.8 ppg Brine w/ 1% by volume CRW-132 and chase w/ 64 bbls 9.8 ppg Brine @ 3 bpm @ 200 si . 14:00 14:30 0.50 7,304 7,338 COMPZ RPCOM OTHR P Insert seals into SBE @ 7,323' and floated seals into SBE to 7,338' MD. 14:30 15:30 1.00 7,338 7,338 COMPZ RPCOM THGR P Land Hanger and Verify alignment of side port, RILDS. PT Top hanger seals to 5,000 psig -good test. Lower seals failed. 15:30 19:30 4.00 7,338 7,338 COMPZ RPCOM THGR T BOLDS and Pull hanger to rig floor, seals pulled out @ 85k up wt. Change out lower hanger seals and RIH and insert seals w/ 45k do wt. Land hanger and Verify side port alignment, RILDS. Test Top hanger seals to 5,000 psig for 10 minutes - Good test. Test lower seals @ 5,000 psig for 10 minutes -.Failed test. Called Town Engr and discuss options -decided to Set TWC and test against Blind Rams for Metal to Metal test. Lay down landing jt, Install TWC and fill BOP. above Blind rams. Pressure Test @ 250 psig and had slow leak off increase to 5,000 psig and bled off. Bleed off pressure and attempt to re-test - failed. Pull TWC. Install BPV. Page 13 of 16 • ':Time: Lo s Date From To Dur S. De th E. De th .Phase Code Subcode T Comment 19:30. 20:00 0.50 7,338 7,338 COMPZ RPCOM SFTY T Held PJSM. Discuss safety & hazard recognition issues. Discuss procedure to nipple down BOP's and nipple up tree & test same. Notified AOGCC of upcoming operation to re air tubin han er. 20:00 00:00 4.00 7,338 7,338 COMPZ RPCOM NUND T Nipple down 11" BOP stack, set back on stand in cellar. Change out u er VBR's. 2/25/2010 NU tree. Install BPV. Move rig off of well. Remove 11" BOP stack from cellar. Install 13 5/8" BOP Stack. Spot rig over 1J-158. Nipple down tree. Install blanking plug. NU 13 5/8" BOP stack. Tighten cap on annular. RU to test BOP's. Total fluid loss for the da = 0 BBLS. Cum Fluid Loss = 3,763 bbls. 00:00 03:30 3.50 7,338 7,338 COMPZ RPCOM NUND T Prep tree. Nipple up tree and perform void test to 5000 PSI. Fill with disel and test, Upper seals only. Pull TWC. Install BPV. 03:30 05:00 1.50 7,338 7,338 COMPZ RPCOM MOB T Continue prep location, rig and cellar for move off of well. Wrap tree for' keeping same warm during BOP swa . 05:00 06:30 1.50 7,338 7,338 COMPZ RPCOM MOB T Move rig off of well. Pull 11" BOP stack out and set on stand. 06:30 11:00 4.50 7,338 7,338 COMPZ RPCOM OTHR T PU 13 5/8" BOP and Stack up. Set back 11:00 13:00 2.00 7,338 7,338 COMPZ RPCOM RURD T Move rig over well and set down. Berm u and re are to rocede. 13:00 14:30 1.50 7,338 7,338 COMPZ RPCOM NUND T ND Tree and Adapter. Install Blankin lu for test. 14:30 15:00 0.50 7;338 7,338 COMPZ RPCOM SFTY T Held PJSM. Discuss safety & hazard recognition issues. Discuss procedure to nipple up BOP's & test same. Notified AOGCC of test. 15:00 00:00 9.00 7,338 7,338 COMPZ RPCOM NUND T NU 13 5/8 BOPE, tighten cap on annular after element had been than ed out reviousl . 2/26/2010 Complete NU of BOP stack. RU & Test BOP's to 250 / 2500 PSI. Witness of test waived by AOGCC rep Jeff Jones. Rig up and pull tbg hanger to rig floor. Change out lower bushing assembly on hanger and retest same. Resplice I -wire, and test same. Make up and re-land tubing hanger. Drop ball & Rod. Pressure test tubing and IA as per program. Pressure down IA to shear SOV at 2400 PSI. Install BPV. ND BOP stack breaking each flange for set back on skid. Total fluid loss for the da = 85 BBLS. Cum Fluid Loss = 3,848 bbls. 00:00 -01:00 1.00 7,338 7,338 COMPZ RPCOM NUND T Continue NU 13 5/8 BOPS 01:00 06:30- 5.50 7,338 7,338 COMPZ RPCOM BOPE T Test BOP's, including choke manifold and valves. test manuals and HCR's, and all floor safety valves. perform Koomey test. Initial 200 PSI gained in 23 Secs, with full 3000 PSI in 1 in 58 secs. 6 nitrogen bottles with avg 2500 PSI. Witness of test waived by AOGCC rep Jeff Jones. 06:30 07:30 1.00 7,338 7,338 COMPZ RPCOM MPSP T Pull Blanking plug and HBPV 07:30 09:00 . 1.50 7,338 7,338 COMPZ RPCOM OTHR T MU landing joint and RU to Circulate, BOLDS Page 14 of 16 • `Time Lo s :Date From To Dur S De th E De th Phase Code Subcode T Comment 09:00 -16:00 7.00 7,338 7,304 COMPZ RPCOM HOSO T Fill TBG with charge pump, Unland Hanger @ 150k and Pull seals from SBE @ 75 to 85k. Pull hanger to floor -Outer bushing had damage to the O-rings and Metal seal. Test Heat trace -Good, Test I-tec wire above penetrator -failed, Test below penetrator -failed, Check splice - parted, I-tec wire below splice test good - 1,600 psi and 63 degrees. Disconnect heat trace and break out hanger joint, mouse hole hanger jt and change out outer bushing. Install New outer bushing and MU to TBG string. RIH and reconnect Heat Trace -Test Good - 48 gig olms, 76 gig olms, .and 52 gig olms. Re-splice I-tec wire and test -.1,600 psi and 63 de tees. 16:00 16:30 0.50 7,304 7,338 COMPZ RPCOM CIRC T Pump 25 bbls CRW 132.1 % by volume CI 9.6 ppg and chase w/ 64 bbls 9.8 brine. 16:30 17:00 0.50 7,338 7,338 COMPZ RPCOM OTHR T Lower TBG and stab seals into SBE, Land han er, RILDS. 17:00 18:00 1.00 7,338 7,338 COMPZ RPCOM THGR T Test Lower TBG hanger void @ 250/5,000 for 10 minutes -Lower seals passed. Test upper TBG hanger void @ 250/5,000 for 10 minutes - U er seals assed. 18:00 23:00 5.00 7,338 7,338 COMPZ WELCTI PRTS P Drop roller stem ball and rod. Steam thaw frozen choke & kill lines. RU to PT TBG @ 3,000 psig for 15 minutes,observed no flow from the IA. Bleed back to 1700 psig and PT IA @ 3,000 psig for 30 minutes. Bleed off IA and TBG to 0 psig. Pressure up on IA and shear SOV @ 4,937' @ 2400 PSI to shear, observing flow in the tubing. Allow preesure to bleed off. Rig down & pull landing joint. Install BPV as per Vetco re . 23:00 23:30 0.50 0 0 COMPZ WELCTL SFTY P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure to nipple down BOP stack. 23:30 00:00 0.50 0 0 COMPZ WELCTL NUND P Nipple down 13 5/8" BOP stack. Make breaks on all flanges. Prep to mount on skid, greasing all valves and rin rooves. 2/27/2010 Continue ND 13 5/8" BOP stack. Perform megger test. NU Tree & test same. Secure well. Prep rig for move. 00:00 04:00 4.00 0 0 COMPZ WELCTI NUND P Continue nipple down 13 5/8" BOP stack. Make breaks on all flanges. Prep to mount on skid, greasing all valves and rin rooves. 04:00 04:30 0.50 0 0 COMPZ WELCTL NUND P Perform final megger test on I-wire & heat trace as er Centrilift re . Page 15 of 16 Time;Lo s Date From To Dur S. De th E. De th` Phase Code Subcode T Comment 04:30 08:00 3.50 0 0 COMPZ WELCTL NUND P _ Nipple up tree as per Vetco rep. and PT Void and Tree @ 250 / 5,000 si . - ood tests. 08:00 08:30 0.50 0 0 COMPZ WELCTL MPSP P Pull test plug 08:30 09:00 0:50 0 0 COMPZ WELCTL SFTY P Held PSM with LRS and rig crew on Freeze protecting well and PT lines rior to um in . 09:00 10:30 1.50 0 0 COMPZ WELCTL CIRC P RU Little Red Services and PT lines @ 2,500 psig. Pump 100 bbls of diesel down IA @ 2 bpm @ 750 psig ICP and FCP @ 1,050 psig. RD LRS 10:30 12:30 2.00 0 0 COMPZ WELCTL OTHR P Tie TBG into IA and allow well to U-tube FP for 2 hrs. Final SIP = 275 psig TBG, 200 psig on IA and 0 psig on OA. 12:30 13:00 0.50 0 0 COMPZ WELCTL MPSP P Lubricate in 4" H-BPV and Secure well. La down Lubricator 13:00 16:30 3.50 0 0 COMPZ MOVE OTHR P Dress Tree and blow down cellar pump lines in Prep for rig move. Back rig off 1J-158 and remove mats and containment from around cellar. RU super sucker and clean cellar. Hand over well to 1 J Pad operator - Greg Whitehead. Release Nordic Rig 3 @ 16:30 hrs on 2-27-10 Page 16 of 16 ~ ~ ~~~~ DATA SUBMITTAL COMPLIANCE REPORT 6/22/2009 Permit to Drill 2070550 Well Name/No. KUPARUK RIV U WSAK 1J-158L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23356-60-00 MD 12261 TVD 3236 Completion Date 6/20/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATIDN Types Electric or Other Logs Run: GR/RES (data taken from Logs Portion of Master Well Data Maint ~ Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Ty ~ Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D D Asc Directional Survey 0 12261 Open 8/23/2007 pt 15510 LIS Verification 3371 12261 Open 10/3/2007 LIS Veri, GR, FET, RPS, ROP D C Lis 15510~fnduction/Resistivity 3371 12261 Open 10/3/2007 LIS Veri, GR, FET, RPS, ~ ROP w/graphics ED C 17990~ee Notes 0 0 Open 5/5l2009 EWR logs in CGM, EMF and PDS graphics og Induction/Resistivity 25 Col 121 12261 Open 5/5/2009 MD ROP, EWR, DGR og Induction/Resistivity 25 Col 121 3236 Open 5/5/2009 TVD EWR, DGR Well Cores/Samples Information: Sample ~ Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y~ Daily History Received? ~~ N Chips Received? 1~7#~ Formation Tops ~N Analysis Y-/-P!~ Received? DATA SUBMITTAL COMPLiANCE REPORT 6/22/2009 Permit to Drill 2070550 Well Name/No. KUPARUK RIV U WSAK 1J-158L1 Operator CONOCOPHILLIPS ALASKA INC MD 12261 ND 3236 Completion Date 6/20/2007 Completion Status 1-OIL Current Status 1-OIL Comments: Compliance Reviewed By: Date: API No. 50-029-23356-60-00 UIC N ~ ~ ~ ~ ~~~~. ~~~ ~°~1~~1~/~~'~'I'~,~.. '~"~o State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Ancharage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-158+L1 May 1, 2009 AK-MW-5034555 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Bryan Burinda, Sperry Drilling, Arctic Blvd., Anchorage, AK 99518 1J-158+L1 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23356-00,60 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23356-00,60 Digital Log Images 2 CD Rom 50-029-23356-00,60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNII~IG AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Ancharage, Alaska 99518 Office: 907-273-3536 F~: 907-273-3535 BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Bryan.Burinda~,a7hal~iburton.com ~,I ~~ T~ate: " , ; ,~ ~~ , ~ ;- ~ Si~ned: ~~ 'd~~` ~~~~~ ~~' l ~~ ~ ~i' ~ ~ ; a-- ~--~ ~ ,~ ~- .~~ j l . ~ ~ ~ ~ • • ConocoPhillips May 24, 2008 Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7~' Ave. Ste. 100 Anchorage, AK 99501 ~ Robert Buchholz / Robert Christensen Production Engineering Tech. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone:(907)659-7535 Fax:659-7314 ir~ ~ I ~~ ~~ ;° I~AY 2 g 20G~~ ~lask~ OsE & Gas Cons. Cam:•.,~<.;.~; Anchoragz Dear Mr. Maunder, ConocoPhillips Alaska, Inc. has changed the artificial lift method in the West Sak 1J-158 and 1J-158L1 multilateral oil production wells. Enclosed you will find 10-404 Reports of Sundry Well Operation recording the change in artificial lift method to GL (Gas lifted) due to a failed ESP (Electrical Submersible Pump)• If you have any questions regarding this matter, please contact myself or Robert Buchholz at 659-7535. Sincerely, Robert D. Christensen Attachments ~b~ -(~`J~ ` ~. ' ' `' , ~ - ' ' STATE OF ALASKA . ~ ALf~SKA OIL AND GAS CONSERVATION COMMISSION ' . REPORT'OF SUN`DRY W~LL OPERATIONS 1. operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ~ Stimulate ~ Other ~ ESP to GL Alter Casing ^ Pull Tubing ^ Pertorate New Pool Q Waiver ^ Time Extension 0, Change Approved Program ^ Operat. Shutdovan[] Pertorate ~- Re-enter Suspended Weil ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: W Q ConocOPhillips Alaska, Inc. Development ~^ Exploratory ^ 207=055 / 30 3. Adtlress: Strati ra hic g p ^ Service ^ 6. API Number: . P. O. Box 1b0360, Anchorage, Alaska 99510 50-029-23356-60 7. KB Elevation (ft): 9. WeII.Name~and Number: : RKB 121' 1J-158L1 8. Property Designation: 10. Field/Pool(s): ALK 25660, 25661, 25663 Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 12269' feef true vertical 3236' feet Plugs (measured) Effective Depth measured 12251 feet Junk (measured) true vertical 3236 feet Casing Length Size MD ND _ Burst Collapse Structural CONDUCTOR 12T 20" ' 12T 121' SURFACE 3272' 10-3/4" 3393' 2153' PRODUCTION 7769' 7-5/8" 7890' 3322' D-SAND WINDOW 1' 7-5/8" ~ 7444' 3250' 0.SAND SLOTfED LINER 4611' ~ ' 4-1 /2" ~ 12251' ~ 3236' ~y ~ ~ ~ ~ ` ~~ ~ d~t v Perforation depth: Measured depth: 7702'-8608;8908'-9892' ; 11216'-12206' ' ' ~A~ 2 g z~~~ true vertical depth: 3258 -3227; 3257'-3243'; 3242'-3235' ~ ~ ~ ~ ~ ~ ~i~sk~ ~il $-~ Gas C ~~. ~ommission Tubing (size, grade, and measured depth) 4-1/2" , L-80, 72~1' MD. ADC~i01'a~8 Packers & SSSV (type & measured depth) D-SAND BAKER PAYZONE L-1 ECP PKR = 7581' no SSSV no SSSV 12. Stimulation or cement squeeze summary: ~ Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or lnjection Data Oil-Bbl Gas-Mcf Water-6bl Casin Pressure Tubin Pressure Prior to well operation 806 780 29 178 229 Subsequent to operation 1959 501 42 909 245 14. Attachments 15. Well Class after work: Copies of 4ogs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: OilO Gas^ ` WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A contact Bob Christensen / Bob Buchholz Printed Nam Robert D. Chri ensen r~tie Production Engineering Technician Signature 1! Phone: 265-6471 Date ~~~ ~~~I l \Cj ~ ~~ . y,-,.~~ ~~,. Form 10-404 Revised 04/2006 " ~~~~ ``~~ ~`~ `~ ~~~~ Sul~m~t Original Only 'f ~ ~ 1J-158L1 DESCRIPTION_ OF WORK COMPLETED SUMMARY Date Event Summary 05/19/08 Well Retumed to production as a gas lifted oil producer 05/09/08 PULLED 1" SOV a~ 2135' RKB. RERLACED WITH 5/16" ORIFICE. ,PULLED 4.5" SLIP CATCHER @ 2319' WLM. JOB COMPLETE. 05/03/08 PULL ESP PUMP 48" @ 2880' WLM, SET 4 1/2° SLIP STOP GSUB @ 2308' WLM, JOB IN PROGRESS West Sak 1J-158 (PTD# 207-054) Report of Conversion to Gaslift Page 1 of 1 ~ i Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: 7uesday, May 06, 2008 1:55 PM To: 'NSK Problem Well Supv'; Regg, James B(DOA) Cc: NSK Well integrity Proj; NSK West Sak Prod Engr; CPF1 DS Lead Techs Subject: RE: West Sak 1 J-158 (PTD# 207-054) and 1J-158L1 (PTD# 207-055) Report of Conversion to Gastift ~ Martin, When you send in the 404, be sure to send in on for 1 J-158L1 as well. Tom Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Monday, May 05, 2008 1:35 PM To: Maunder, Thomas E(DOA); Regg, James B(DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv; NSK West Sak Prod Engr; CPFi DS Lead Techs Subject: West Sak 1J-158 (PTD# 207-054) Report of Conversion to Gaslift «1J-158 Wellbore Schematic.pdf» 7om/Jim, West Sak ESP producer (PTD# 207-054) experienced an ESP pump failure on 03/01/Q8 due to solids production. A second pump was installed on 04/20/08 and even though the motor was operational, the pump system failed to lift #luids to surFace. Our immediate plan is to convert the well to gaslift to allow it to clean up and then evaluate the possibility of returning to ESP as a means of artificial lift. This well was permitted with gaslift as a back-up so our intent is to submit a 10-404 after wellwork is complete. Attached is the most recent wellbore schematic. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Ce!! 907-943-1720 / 9 999 Pager 907-659-7000 #909 5/6/2008 ~ * WELL LOG TRANSMITTAL To: State of Alaska September 7, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1J-1~8 L1 AK-MW-5034555 1 LDWG formatted CD Rom with verification listing. API#: 50-029-233 56-60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMTTTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99~ 18 _, ~ - .. ~~ ~ ~---~3 ' -~- """' Date: "~ ~~, ~_, _ .. ._ .._ e .y=._~ ~ Signed: ~s ~~~~~ ~a,~_~~ -~ ~~v 1~ ~ • 31-J u I-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-158L1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 7,367.36' MD Window / Kickoff Survey 7,443.00' MD (if applicable) Projected Survey: 12,261.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~. 3 1~, ~~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) p~ ~~- OSS ~ ~ ~~~~~~~~ STATE OF ALASKA AIASKA OIL AND GAS CONSERVATION COMMISSION ~~~ ~`L ~OO/ WELL COMPLETION OR RECOMPLETION REP ~ 1a. Well Status: pil Q, Gas Plugged Abandoned ~ Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: ~ Development ~/~, i" ~'Exploratory ^ Service ^ Stratigraphic Tesi ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or aband.: June 20, 2007 ' 12. Permit to Drill Number: 207-055 /• 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: June 10, 2007 ~ 13. API Number. 50-029-23356-60 ~ 4a. Location of Well (Governmental Section): Surface: 2055' FSL, 2550' FEL, Sec. 35, T11N, R10E, UM ~ 7. Date TD Reached: June 14, 2007 ! 14. Well Name and Number: 1J-158L1 ' Top of Productive Horizon: 1040' FSL, 2243' FEL, Sec. 34, T11 N, R10E, UM 8. KB (ft above MSL): Ground (ft MSL): 121' MSL - 15. Field/Pool(s): Kuparuk River Field Total Depth: 1533' FSL, 1882' FEL, Sec. 3, T10N, R10E, UM 9. Plug Back Depth (MD + ND): 12251' MD / 3236' ND West Sak Oil Pool ~ 4b. Location of Wetl (State Base Plane Coordinates): Surface: x- 558659 ~ y- 5945867 ~ Zone- 4 10. Total Depth (MD + ND): - 12261' MD / 3236' TVD r 16. Property Designation: ALK 25660, 25661, 25663 TPI: x- 553696 y- 5944815 Zone- 4 Total Depth: x- 554099 ~ ~- 5940030 ~ Zone- 4 ~ 1. SSSV Depth (MD + ND): none 17. Land Use Permit: 470, 471, 472 18. Directional Survey: Yes Q/ No~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): 2127' ND 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): cop window @ 7443~-7ass~ nnD GR/RES 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD pULLED 20" x 34" 78.6# H-40 41' 121' 41' 121' 42" 250 sx AS 1 10.75" 45.5# L-80 41' 3393' 41' 2153' 13.5" 569 sx Class G, 18o sx Class G 7.625" 29.7# L-80 41' 7890' 41' 3323' 9.875" 35o sx Class G 4.5" 11.6# L-80 7440' 7680' 3249' 3259' 6.75" slotted liner 4.5" 11.6# L-80 7640' 12251' 3235' 3236' 6.75" slotted liner 23. Open to production or injection? Yes ~ No ~ If Yes, list each 24. TUBING RECORD Interval open (MD+7VD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore none slotted liner from 8608'-8908', 11087'-11216' MD ' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n!a 26. PRODUCTION TEST Date First Production July 23, 2Q07 Method of Operation (Flowing, gas lift, etc.) ESP oil - shares production with 1J-158 Date of Test 7/24/2007 Hours Tested 14 hours Production for Test Period --> OIL-BBL 1218 ' GAS-MCF 142 WATER-BBL 46 CHOKE SIZE 19% GAS-OIL RATIo 148 Flow Tubing press. 263 psi Casing Pressure not available Calculated 24-HOUr Rate -> OIL-BBL 1986 ~ GAS-MCF 294 WATER-BBL 79 OIL GRAVITY - API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes No ~ Sidewall Cores Acquired? Yes No Q If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical resuits per 20 AAC 25.071. 4';pMPl.ET 0 ~~ NONE ~ ~ Form 10-407 Revised 2/2007 CONTINUED ON~~li~t'!~ A~IG ~~~qpr ~ g~•~ QR1~IN '~~~ ..~~~~~ AL ~ ~ ~ 28. GEOLOGIC MARKERS (List all formations and ma ers encountered): 29. FORMATION TESTS NAME MD ND Well tested? Yes ~ No If yes, list intervals and formations tested, Pefmaf~ost - Top SurfBCe sulfiaCe briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1655' 1507' (est.) , needed, and submit detailed test information per 20 AAC 25.071. T-3 3300' 2127' K-15 3300' 2127' Ugnu C 5690' 2809' Ugnu B 6120' 2931' Ugnu A 6280' 2977' K-13 6645' 3075' West Sak D 7440' 3249' N/A Formation at total depth: West Sak D' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, slotted liner detail sheet 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ContBCt: Dennis Hartwig @ 265-6862 Printed Name and mas Title: Drillinq Team Leader ~ / d~ Signature Ph ne ~ / ~ ~~ ~~~ Date ('7 Sharon Allsup-Drake ~ ° ~ ~~~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases irt Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Sait Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 ~ • Halliburton Company Survey Report =,'Go~p~any: CortocoPhillips Alaska [nc: ~ _ Date: 7f312Qt~7 Titne: t19.~7 2•7 :... ;; ;;,P.a~e. ' 1': „ FY~id: . Kupar~k F~iue:r ~'Jnit C~-nrdinatc~TE~Ref~ea~e Wetl: ~J-1~$ 'Frue i~arth ' Sate: Kup~ruk 'f~1 P~d ~.'S'ertical ("~Y~~ 12~er+~tee ~ 1J 1 ~$L~ ~~i ~~" ` = ~'4'el~. ~ '~;~-'f ~i ~ " ~ ~eeirun (~'~}Re~`er~ne~ '~ ~18[I {(~.~1(1t~f Q.(I~E `k$Q.{I(TA~j . VWellpath: 1,~ 1~8L~ ~ur~e~ ~a~~at~n ~Tetho~i. ' ~Ai~s-mGr~t C~[rvat~a~e : 1)b ~.Ck'ac[~ Field: Kuparuk River Unit North Slope Alaska ~ United States ; MapSystem:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 I~ Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: 1 J-158 Slot Name: ~ Weli Position: +N/-S -51.91 ft Northing: 5945866.71 ft' Latitude: 70 15 45.747 N +E/-W -131.48 I ft Easting : 558658.89 ft~ Longitude: 149 31 32.833 W Position Uncertainty: 0.00 ft Welip ta h 1J-158L1 Drilled From: 1J-158 500292335660 Tie-on Depth: 7367.36 ft ~ Current Datum: 1 J-158LL• Magnetic Data: 5/24/2007 Height 121.55 ft. Above System Declination: Datum: Mean Sea Level 23.34 deg Field Strength: 57611 nT Mag Dip Angle: 80.79 deg Ver[ical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 40.55 0:00 0.00 180.00 ! ~ Survey Program for DeSnitive Wellpath ~ Date: 7/3/2007 Validated: No Version: 2 ; Actual From To Survey Toolcode Tool Name ~ ft ft 114.00 747.00 1J-158 gyro (114.00-747.00) (0 CB-GYRO-SS Camera based gyro single shot 787.24 7367.36 1 J-158 (787.24-12203.60) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7443.00 12197.41 1J-158L1 (7443.00-12197.41) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC ~ Survey ;, -:M#~ 1nc1 Aziru ' , T"~i? :'`. . : Sys TVll i~f5 ' Elt~` ;; -- ; , M~~N 14f~p~ Tool ` ft ~ deg ~l+e~ ~ : ~ - ~ ft ft '~~ fit ft ~ ~ ~ ~ ft „::' ft'~, ' : ~. . ~ _ ~ ~ .. . . _. _, . , - 40.55 0.00 0.00 40.55 -81.00 0.00 .. .. ~ 0.00 , 5945866.71 558658.89 TIE LINE 114.00 0.66 246.29 114.00 -7.55 -0.17 -0.39 5945866.54 558658.50 CB-GYRO-SS 2T4.00 Q.43 231.18 213.99 92.44 -0.64 -1.21 5945866.06 558657.69 CB-GYRO-SS 313.00 1.00 254.75 312.99 191.44 -1.10 -2.33 5945865.59 558656.57 CB-GYRO-SS ~ 367.00 1.83 273.52 366.97 245.42 -1.17 -3.65 5945865.51 558655.25 CB-GYRO-SS ~ 407.00 2.48 278.24 406.94 285.39 -1.00 -5.14 5945865.67 558653.76 CB-GYRO-SS ~ 502.00 4.21 287.43 501 J8 380.23 0.33 -10.50 5945866.96 558648.39 CB-GYRO-SS j 596.00 6.19 283.81 595.38 473.83 2.58 -18J1 5945869.14 558640.16 CB-GYRO-SS ~ 691.00 8.98 280.79 689.54 567.99 5.19 -30.97 5945871.66 558627.88 CB-GYRO-SS 747.00 10.70 278.96 744.72 623.17 6.82 -40.40 5945873.21 558618.44 CB-GYRO-SS 787.24 11.99 274.57 784.17 662.62 7.73 -48.26 5945874.06 558610.58 MWD+IFR-AK-CAZ-SC 882.56 14.09 281.19 877.03 755.48 10.77 -69.52 5945876.94 558589.30 MWD+IFR-AK-CAZ-SC 978.19 17.88 280.38 968.95 847.40 15.68 -95.38 5945881.64 558563.40 MWD+IFR-AK-CAZ-SC 1072.43 22.79 279.34 1057.29 935.74 21.25 -127.64 5945886.96 558531.10 MWD+IFR-AK-CAZ-SC 1167.82 26.09 278.50 1144.12 1022.57 27.35 -166.63 5945892.76 558492.07 MWD+IFR-AK-CAZ-SC ~ 1261.63 28.67 277.19 1227.42 1105.87 33.22 -209.37 5945898.29 558449.29 MWD+IFR-AK-CAZ-SC ~ 1356.70 34.30 273.91 1308.46 1186.91 37.90 -258J6 5945902.59 558399.87 MWD+IFR-AK-CAZ-SC ~ ~ 1451.29 39.33 274.89 1384.17 1262.62 42.28 -315.25 5945906.53 558343.35 MWD+IFR-AK-CAZ-SC 1546.78 43.53 274.95 1455.74 1334.19 47.70 -378.19 5945911.46 558280.37 MWD+IFR-AK-CAZ-SC 1640.49 46.81 276.45 1521.80 1400.25 54.32 -444.31 5945917.56 558214.22 MWD+IFR-AK-CAZ-SC 1735.20 51.44 277.59 1583.77 1462.22 63.10 -515.36 5945925.78 558143.10 MWD+IFR-AK-CAZ-SC 1831.07 56.45 281.29 1640.19 1518.64 75.88 -591.76 5945937.97 558066.62 MWD+IFR-AK-CAZ-SC 1927.51 62.60 282.27 1689.08 1567.53 92.86 -673.08 5945954.32 557985.17 MWD+IFR-AK-CAZ-SC I 2021.83 64.91 284.43 1730.79 1609.24 112.41 -755.37 5945973.22 557902.74 MWD+IFR-AK-CAZ-SC ~ 2116.85 67.59 284.71 1769.05 1647.50 134.29 -839.54 5945994.44 557818.41 MWD+IFR-AK-CAZ-SC 2211.83 71.44 284.35 1802.28 1680.73 156.60 -925.65 5946016.08 557732.13 MWD+IFR-AK-CAZ-SC ~ 2306.45 72.28 281.78 1831.75 1710.20 176.92 -1013.23 5946035.72 557644.41 MWD+IFR-AK-CAZ-SC 2400.14 71.82 282.55 1860.62 1739.07 195.70 -1100.36 5946053.82 557557.14 MWD+IFR-AK-CAZ-SC • ~ Halliburton Company Survey Report ~- ~: ~ninpany: ConocnPhillips Alask~i tnc. Date. 7f3%2Ut}7" `. : 7'ilrie €~1.~7 27. .. . : Pag~ ;,, ~ : : ~lr~i ' 1€~paruk £2iver tJnik Co-nrdiuat~iE}Ref~r~~ee: . , i~fe[4:1,1 158 ~nie.~ptttt - ~xf~: KCip~~ttk '~~. Pad , . ~ ~ ~ "~~~t~ca-:f"~"~'~}~iefi+~rcqCe ~ _: '~J-1~~f~1 1~'i:~ ~4'Vel~;. : '#,~'158 ~ ~~etiort`~VS} ~~e!'e~ce ~ . ` 1N~t~: (Q.Q01~ Q t#(I~ ~~t3 Ut1R~~ Weltpath'a „1,J-la8~l: 5urvey Cakulahag=l~Iethod Mit1ir~1uti1 Griruafure ° T~b ~}r'dCi4 Survey 11^ID Iucl i~zim ' TVD ' SysTVD, 1~T(S E/W -"z~: .= l~agN . i MapE Tattt .: fit . dec~ dey +. ft, ft ft ft ..:.' ft ft' 2495.46 72.08 280.91 1890.16 1768.61 214.12 -1189.09 5946071.55 557468.28 MWD+IFR-AK-CAZ-SC 2590.76 71.82 281.82 1919.69 1798.14 231.98 -1277.93 5946088.71 557379.32 MWD+IFR-AK-CAZ-SC 2686.55 70.94 282.83 1950.27 1828.72 251.35 -1366.61 5946107.39 557290.50 MWD+IFR-AK-CAZ-SC i 2782.07 72.57 282.24 1980.18 1858.63 271.04 -1455.16 5946126.38 557201.80 MWD+IFR-AK-CAZ-SC i 2877.07 73.81 279.86 2007.65 1886.10 288.46 -1544.41 5946143.11 557112.43 MWD+IFR-AK-CAZ-SC ~ 2972.68 73.64 279.45 2034.45 1912.90 303.85 -1634.89 5946157.79 557021.84 MWD+IFR-AK-CAZ-SC 3067.67 73.89 280.82 2061.01 1939.46 319.90 -1724.66 5946173.14 556931.95 MWD+IFR-AK-CAZ-SC 3162.70 74.27 283.40 2087.08 1965.53 339.08 -1814.00 5946191.61 556842.47 MWD+IFR-AK-CAZ-SC 3257.92 72.08 283.73 2114.64 1993.09 360.45 -1902.60 5946212.29 556753.72 MWD+IFR-AK-CAZ-SC ~ 3351.70 74.15 283.93 2141.87 2020.32 381.90 -1989.73 5946233.06 556666.44 MWD+IFR-AK-CAZ-SC ~ 3405.17 73.81 283.03 2156.63 2035.08 393.88 -2039.71 5946244,65 556616.37 MWD+IFR-AK-CAZ-SC ( 3468.81 73.46 281.99 2174.56 2053.01 407.11 -2099.32 5946257.41 556556.67 MWD+IFR-AK-CAZ-SC ~ i ~ 3564.25 73.70 280.55 2201.54 2079.99 425.00 -2189.10 5946274.60 556466.76 MWD+IFR-AK-CAZ-SC 3659.14 73.18 280.10 2228.59 2107.04 441.30 -2278.58 5946290.21 556377.16 MWD+IFR-AK-CAZ-SC 3753.81 72.91 279.58 2256.20 2134.65 456.78 -2367.80 5946304.98 556287.83 MWD+IFR-AK-CAZ-SC 3847.72 72.86 280.25 2283.83 216228 472.23 -2456.21 5946319.75 556199.31 MWD+IFR-AK-CAZ-SC 3944.00 73.09 280.55 2312.02 2190.47 488.85 -2546.76 5946335.66 556108.64 MWD+IFR-AK-CAZ-SC 4037.89 73.23 280.72 2339.22 2217.67 505.43 -2635.08 5946351.55 556020.21 MWD+IFR-AK-CAZ-SC 4133.01 73.04 281.55 2366.82 2245.27 523.01 -2724.39 5946368.43 555930.77 MWD+IFR-AK-CAZ-SC 4227.91 73.43 282.00 2394.19 2272.64 541.56 -2813.35 5946386.28 555841.68 MWD+IFR-AK-CAZ-SC ~ 4322.58 73.30 282.19 2421.29 2299.74 560.56 -2902.04 5946404.60 555752.85 MWD+IFR-AK-CAZ-SC ! ~ 4415.25 73.36 280.99 2447.88 2326.33 578.40 -2989.01 5946421 J5 555665.76 MWD+IFR-AK-CAZ-SC ~ 4510.57 73.80 278.55 2474.83 2353.28 593.91 -3079.10 5946436.56 555575.55 MWD+IFR-AK-CAZ-SC 4606.55 73.63 274.02 2501.75 2380.20 603.99 -3170.65 5946445.93 555483.93 MWD+IFR-AK-CAZ-SC 4702.16 73.11 271.03 2529.12 2407.57 608.03 -3262.16 5946449.25 555392.40 MWD+IFR-AK-CAZ-SC 4797.79 73.42 268.95 2556.66 2435.11 608.01 -3353.74 5946448.52 555300.84 MWD+IFR-AK-CAZ-SC 4892.90 73.37 265.36 2583.85 2462.30 603.49 -3444.75 5946443.29 555209.88 MWD+IFR-AK-CAZ-SC 4988.37 73.50 262.95 2611.07 2489.52 594.17 -3535.77 5946433.27 555118.94 MWD+IFR-AK-CAZ-SC 5083.68 73.42 258.91 2638.21 2516.66 579.77 -3625.98 5946418.17 555Q28.86 MWD+IFR-AK-CAZ-SC 5178.68 73.76 257.31 2665.05 2543.50 561.00 -3715.15 5946398.70 554939.84 MWD+IFR-AK-CAZ-SC 5273.36 73.24 255.35 2691.95 2570.40 539.55 -3803.35 5946376.56 554851.82 MWD+IFR-AK-CAZ-SC ' i 5368.57 73.85 252.57 2718.92 2597.37 514.32 -3891.10 5946350.65 554764.28 MWD+IFR-AK-CAZ-SC ~ ~ 5463.49 73.74 248.68 2745.42 2623.87 484.09 -3977.06 5946319.75 554678.56 MWD+IFR-AK-CAZ-SC i 5557.90 73.42 244.77 2772.12 2650.57 448.31 -4060.24 5946283.34 554595.68 MWD+IFR-AK-CAZ-SC ~ 5654.15 73.82 241.51 2799.27 2677.72 406.59 -4142.60 5946240.98 554513.64 MWD+IFR-AK-CAZ-SC 5749.16 73.55 239.50 2825.96 2704.41 361.70 -4221.96 5946195.48 554434.64 MWD+IFR-AK-CAZ-SC 5844.60 73.29 235.52 2853.20 2731.65 312.58 -4299.10 5946145.76 554357.90 MWD+IFR-AK-CAZ-SC I 5939.81 73.63 232.32 2880.32 2758.77 258.84 -4372.85 5946091.45 554284.57 MWD+IFR-AK-CAZ-SC ~ 6034.10 73.36 229.38 2907.11 2785.56 201.77 -4442.95 5946033.85 554214.93 MWD+IFR-AK-CAZ-SC 6129.69 73.69 226.49 2934.22 2812.67 140.36 -4511.00 5945971.92 554147.37 MWD+IFR-AK-CAZ-SC 6224.52 73.23 222.91 2961.23 2839.68 75.76 -4574.93 5945906.82 554083.95 MWD+IFR-AK-CAZ-SC 6319.01 73.42 218.91 2988.35 2866.80 7.37 -4634.19 5945837.98 554025.23 MWD+IFR-AK-CAZ-SC 6413.76 73.39 214.12 3015.43 2893.88 -65.58 -4688.20 5945764.61 553971.79 MWD+IFR-AK-CAZ-SC 6509.66 75.19 210.04 3041.40 2919.85 -143.79 -4737.21 5945686.04 553923.40 MWD+IFR-AK-CAZ-SC 6604.80 75.75 206.01 3065.28 2943.73 -225.07 -4780.47 5945604.43 553880.78 MWD+IFR-AK-CAZ-SC 6699.18 74.82 202.34 3089.26 2967.71 -308.33 -4817.85 5945520.89 553844.05 MWD+IFR-AK-CAZ-SC i 6794.20 75.66 198.65 3113.48 2991.93 -394.38 -4850.01 5945434.60 553812.57 MWD+IFR-AK-CAZ-SC i i 6890.73 77.51 193.66 3135.89 3014.34 -484.54 -4876.11 5945344.25 553787.17 MWD+IFR-AK-CAZ-SC 6985.94 77.17 191.20 3156.75 3035.20 -575.25 -4896.10 5945253.39 553767.89 MWD+IFR-AK-CAZ-SC ~ 'i ~~ 7080.84 77.63 190.05 3177.46 3055.91 -666.28 -4913.18 5945162.25 553751.52 MWD+IFR-AK-CAZ-SC ~ 7174.92 77.69 190.10 3197.56 3076.01 -756.76 -4929.25 5945071.64 553736.15 MWD+IFR-AK-CAZ-SC 7271.33 ~- 77.64 - 189.81 3218.16 - 3096.61 -849.53 - -4945.54 - 5944978.76 - 553720.60 - MWD+IFR-AK-CAZ-SC -- ~ ~ Halliburton Company Survey Report ~~mpany: Cd~ocaf?tiillips ~4laska tnc I~ste. . 7/~#'1tiQ7 TF~: ~19:57 2'~ ~ Page: °' 3.. ~~~ ~ - Fieid: ' Kupariek River tJni# ~: °= . ', . ~'q~rdinat~jl'~E} R~f~rQnc~ . .. `, UVleil: 1 J-1 ~ '~tve hlotth '' ; Sife: ' Kuparuk~J Pad Yerticat(°I'YY~}R+efesence: t.~158L1;.1~1.5 ' ~efer~~c~ ~ VRi~ll,(dcQQt~#I.Q4~,48~.{~A~i~ , V4'ellgath^, 1J-958L'1 ~a~ Su" ~ ulatiu ~ Methad ,. : Mi~sirtfuih ~iiCi~~ture ° ` `I1b: (~i'~~te Survey lYi~: ~ Iscl A~im '~ TYI3i '~~ ~SysTVD• ., ~ J"~fS: ~. '~ ~fW~ ' 14iapl~T ~IVi~p~ , ~ ,. :'Fual . ~: , ~:.:~ .. . .~.~ 8g ~ ... . = ~teg ~ ' ft ~t _ ^~ f~ ~ f~ '~~ ~~ ~~ft ~ ~~ , ft~ ~ ~ , _. ' ~ : 7367.36 80.06 189.38 ~ 3236J3 3115.18 -942.42 -4961.24 . 5944885.76 553705.62 . MWD+IFR-AK-CAZ-SC ~ 7443.00 80.27 186.20 3249.65 3128.10 -1016.25 -4971.34 5944811.86 553696.10 MWD+IFR-AK-CAZ-SC i 7523.94 85.51 185.63 3259.67 3138.12 -1096.12 -4979.61 5944731.94 553688.45 MWD+IFR-AK-CAZ-SC 7617.64 91.93 184.98 3261.76 3140.21 -1189.34 -4988.27 5944638.66 553680.52 MWD+IFR-AK-CAZ-SC 7710.86 92.86 184.34 3257.86 3136.31 -1282.17 -4995.83 5944545.78 553673.68 MWD+IFR-AK-CAZ-SC 7804.53 90.57 185.66 3255.06 3133.51 -1375.43 -5003.99 5944452.47 553666.24 MWD+IFR-AK-CAZ-SC I 7898.60 90.45 180.60 3254.22 3132.67 -1469.33 -5009.13 5944358.55 553661.84 MWD+IFR-AK-CAZ-SC ; 7992.59 90.44 175.40 3253.49 3131.94 -1563.23 -5005.85 5944264.69 553665.85 MWD+IFR-AK-CAZ-SC 'i 8087.33 92.05 172.60 3251.43 3129.88 -1657.41 -4995.95 5944170.59 553676.48 MWD+IFR-AK-CAZ-SC i i 8180.67 92.73 168.93 3247.54 3125.99 -1749.45 -4980.99 5944078.68 553692.16 MWD+IFR-AK-CAZ-SC ' 8274.62 92.66 167.17 3243.12 3121.57 -1841.26 -4961.56 5943987.04 553712.30 MWD+IFR-AK-CAZ-SC I 8368.42 93.54 168.41 3238.05 3116.50 -1932.80 -4941.75 5943895.66 553732.82 MWD+IFR-AK-CAZ-SC I 8462.75 93.16 170.79 3232.54 3110.99 -2025.41 -4924.75 5943803.19 553750.54 MWD+IFR-AK-CAZ-SC ~ 8555.55 92.48 171.24 3227.97 3106.42 -2116.96 -4910.27 5943711.77 553765.73 MWD+IFR-AK-CAZ-SC ~ 8649.21 85.32 169.97 3229.77 3108.22 -2209.29 -4895.00 5943619.57 553781.72 MWD+IFR-AK-CAZ-SC ~ i 8743.51 83.64 169.36 3238.84 3117.29 -2301.62 -4878.16 5943527.38 553799.27 MWD+IFR-AK-CAZ-SC ~ 8836.34 82.77 170.25 3249.82 3128.27 -2392.34 -4861.85 5943436.80 553816.30 MWD+IFR-AK-CAZ-SC 8930.35 86.74 174.07 3258.42 3136.87 -2485.05 -4849.09 5943344.20 553829.77 MWD+IFR-AK-CAZ-SC 9024.86 91.25 174.46 3260,07 3138.52 -2579.05 -4839.65 5943250.29 553839.94 MWD+IFR-AK-CAZ-SC 9118.78 93.41 173.86 3256.26 3134.71 -2672.40 -4830.10 5943157.02 553850.22 MWD+IFR-AK-CAZ-SC 9212.43 90.38 172.41 3253.16 3131.61 -2765.31 -4818.91 5943064.21 553862.13 MWD+IFR-AK-CAZ-SC 9305.79 90.94 172.45 3252.08 3130.53 -2857.85 -4806.62 5942971.78 553875.14 MWD+IFR-AK-CAZ-SC ; 9399.37 91.56 173.29 3250.04 3128.49 -2950.69 -4795.00 5942879.05 553887.48 MWD+IFR-AK-CAZ-SC I i 9492.42 91.00 175.16 3247.96 3126.41 -3043.24 -4785.64 5942786.58 553897.56 MWD+IFR-AK-CAZ-SC ~ 9585.93 90.88 175.00 3246.43 3124.88 -3136.39 -4777.63 5942693.50 553906.30 MWD+IFR-AK-CAZ-SC i i 9680.49 91.12 173.31 3244.78 3123.23 -3230.44 -4768.00 5942599.54 553916.66 MWD+IFR-AK-CAZ-SC ~ j 9774.22 90.57 173.11 3243.40 3121.85 -3323.50 -4756.92 5942506.57 553928.46 MWD+IFR-AK-CAZ-SC ~ 9866.79 90.45 173.33 3242.57 3121.02 -3415.42 -4745.99 5942414.75 553940.11 MWD+IFR-AK-CAZ-SC I 9960.79 91.00 175.95 3241.38 3119.83 -3508.99 -4737.21 5942321.26 553949.61 MWD+IFR-AK-CAZ-SC 10053.50 90.14 175.38 3240.46 3118.91 -3601.43 -4730.20 5942228.89 553957.34 MWD+IFR-AK-CAZ-SC 10147.79 90.88 173.24 3239.62 31 T8.07 -3695.25 -4720.85 5942135.16 553967.42 MWD+IFR-AK-CAZ-SC 10241.80 89.83 172.15 3239.04 3117.49 -3788.49 -4708.90 5942042.02 553980.09 MWD+IFR-AK-CAZ-SC 10335.11 89.09 170.43 3239.92 3118.37 -3880.72 -4694.77 5941949.91 553994.94 MWD+IFR-AK-CAZ-SC 10429.11 89.46 174.10 3241.11 3119.56 -3973.84 -4682.12 5941856.90 554008.31 MWD+IFR-AK-CAZ-SC 10522.50 91.06 178.80 3240.68 3119.13 -4067.02 -4676.34 5941763.78 554014.82 MWD+IFR-AK-CAZ-SC 10615.96 89.58 178.64 3240.16 3118.61 -4160.45 -4674.26 5941670.38 554017.63 MWD+IFR-AK-CAZ-SC 10709.25 87.85 177.80 3242.25 3120.70 -4253.67 -4671.36 5941577.19 554021.26 MWD+IFR-AK-CAZ-SC 10802.76 89.15 177.00 3244.70 3123.15 -4347.05 -4667.12 5941483.86 554026.22 MWD+IFR-AK-CAZ-SC 10896.25 87.18 175.68 3247.70 3126.15 -4440.29 -4661.15 5941390.67 554032.91 MWD+IFR-AK-CAZ-SC 10990.34 88.72 177.66 3251.06 3129.51 -4534.15 -4655.69 5941296.86 554039.10 MWD+IFR-AK-CAZ-SC 11085.64 91.87 180.12 3250.57 3129.02 -4629.42 -4653.85 5941201.63 554041.69 MWD+IFR-AK-CAZ-SC ~ ~ 11178.51 95.83 183.88 3244.33 3122.78 -4721.99 -4657.07 5941109.04 554039.19 MWD+IFR-AK-CAZ-SC ; 11273.51 95.95 183.63 3234.59 3113.04 -4816.28 -4663.26 5941014.71 554033.73 MWD+IFR-AK-CAZ-SC ~ 11366.78 93.60 179.67 3226.82 3105.27 -4909.16 -4665.93 5940921.82 554031.79 MWD+IFR-AK-CAZ-SC ~ I 11460.83 90.88 176.68 3223.14 3101.59 -5003.07 -4662.94 5940827.95 554035.51 MWD+IFR-AK-CAZ-SC 11553.15 89.64 174.70 3222.72 3101.17 -5095.13 -4656.00 5940735.96 554043.17 MWD+IFR-AK-CAZ-SC ~ 11647.52 88.53 174.23 3224.23 3102.68 -5189.04 -4646.90 5940642.13 554053.00 MWD+IFR-AK-CAZ-SC ~ 11741.45 87.67 174.88 3227.34 3105.79 -5282.50 -4637.99 5940548.75 554062.63 MWD+IFR-AK-CAZ-SC ' 11834.08 88.10 176.49 3230.76 3109.21 -5374.80 -4631.03 5940456.52 554070.32 MWD+IFR-AK-CAZ-SC I 11928.37 89.46 176.63 3232 77 3111.22 -5468.89 -4625.37 5940362.48 554076.70 MWD+IFR-AK-CAZ-SC . 12021.15 89.09 177.92 3233.94 3112.39 -5561.56 -4620.96 5940269.86 554081.84 MWD+lFR-AK-CAZ-SC 12115.22 90.26 178.02 3234.48 3112.93 -5655.57 -4617.63 5940175.89 554085.90 MWD+IFR-AK-CAZ-SC ~ ~ 12197.41 88.84 173.96 3235.12 3113.57 -5737.53 -4611.88 5940093.98 554092.28 MWD+IFR-AK-CAZ-SC I ~ ~ Halliburton Company Survey Report Survey ~ 12261.00 88.84 173.96 3236.41 ~ 3114.86 -5800J6 -4605.19 5940030.81 554099.47 PROJECTED to TD ~ ~ 06/10/2007 01:00 02:30 1.50 7,492 7,541 PROD2 STK OTHR P Establish circulation. Pumping 273 gpm w/ 2000 psi. PU wt 170k, SO wt 125k. Orient whipstock face to 47 deg ~~ ~~~ left: Five foof ineasurement in the hole to the top of the ZXP packer @ 7541' ~"~~ (48-1/2' in on stand #76). Set down 20k, PU to 210k- anchor is set. Slack off all wt to shear bolt. Work several times. he i 02:30 05:45 3.25 7,443 7,455 PROD2 STK WPST P Mill a window in the 7- 5/8" casing. Pump a 20 bbls sweep (10 ppg/ 180 vis). Rotate 90 rpm w/ 4-7 k ft Ibs of tor ue. Pum in 329 m w/ 2550 psi. 05:45 07:15 1.50 7,455 7,475 PROD2 STK WPST P Drill new formation. 12' offiull guage / hole (6-3/4"): TOW 7443' (3250' ND) Hole angle 80.27 deg. BOW 7455' (3252' TVD) Hole angle 80.27 de . 07:15 08:00 0.75 7,475 7,430 PROD2 STK CIRC P PU then circulate @ 7430'. Pump a 30 bbl sweep (10 ppg, 200 vis). Rotate 50 r m w/ 4000 ft Ib of tor ue. 08:00 08:15 0.25 7,430 7,475 PROD2 STK OTHR P Slack off through window w/ out pumps and with out rotation. Saw 4-6k drag on the face of the whipstock, both directions. 08:15 08:30 0.25 7,475 7,430 PROD2 STK OTHR P Monitorwell. Static. 08:30 09:00 0.50 7,430 7,430 PROD2 STK CIRC P Pump a dry job. Blow down top drive 09:00 1230 3.50 7,430 195 PROD2 STK TRIP P Pull out of the whole with the milling assembly. Hole took proper dis lacement. 12:30 13:30 1.00 195 0 PROD2 STK PULD P Lay down Baker milling assembly and Sperry Sun MWD (change ouf pulsar). Upper mill was guaged to be fc~il 6-3/4". 13:30 14:00 0.50 0 0 PROD2 STK OTHR P Clear and dean rig floor. 14:00 14:45 0.75 0 0 PROD2 STK OTHR P Pickup and make up wash tool. Flush BOP ram cavities after milling operation. 14:45 15:30 0.75 0 0 PROD2 WELC7 OTHR P Make up testjoint. Rig up testing equi ment. 15:30 21:00 5.50 0 0 PROD2 WELCT BOPE P 14 day BOPE test. Witness of test by AOGCC inspector John Crisp. Test upper pipe rams (3-1/2 x 6" variables) with 4", 4-1/2" and 5" testjoint. Test blind rams and annular to 250 psi low and 300Q psi high: Hold each test f/ 5 min. Test all valves f/ the choke manifold, kill line and choke line the same. Test floor vlaves, top drive IBOP automatic and manual the same. Test accumulatoc • 06/10/2007 21:00 21:30 0.50 0 0 PROD2 WELCT OTHR P Pull test plug. Install Vetco Gray wear bushing with 9" ID, 13-3/8" OD, 38" len th. 21:30 22:15 0.75 0 0 PROD2 WELC OTHR P Blow down top drive, choke line and kill line. Ri down testin e ui ment. 22:15 22:30 0.25 0 0 PROD2 DRILL SFTY P Pre job safety meeting on PU/MU BHA #5. 22:30 00:00 1.50 0 65 PROD2 DRILL PULD P PU/MU BHA#5. 06/11/2007 00:00 0030 0.50 65 92 PROD2 DRILL PULD P Continue to PU/MU BHA #5. 00:30 01:30 1.00 92 92 PROD2 DRILL OTHR P Upload to Sperry Sun MWD. 01:30 02:00 0.50 92 369 PROD2 DRILL TRIP P RIH w/ BHA #5. 02:00 02:30 0.50 369 369 PROD2 DRILL OTHR P Shallow test MWD and GeoPilot. Rotate 30 rpm w/ 1000 ft Ibs of torque. Rot wt 85k. 02:30 06:00 3.50 369 7,304 PROD2 DRILL TRIP P Trip in the hole w/ BHA #5. Record PU and SO wYs every 5 stands. Fill pipe every 20 stands. Calculated dis lacement 53 bbls, actual 43 bbls. 06:00 06:30 0.50 7,304 7,304 PROD2 DRILL CIRC P Fill pipe. Blow down top drive. 0630 08:00 1.50 7,304 7,304 PROD2 RIGMN SVRG P Slip and cut 98' of 1-3/8" drilling line. 08:00 08:30 0.50 7,304 7,304 PROD2 RIGMN SVRG P Service top drive, blocks, and drawworks. 08:30 09:15 0.75 7,304 7,475 PROD2 DRILL TRIP P Continue trip in the hole to 7430', then slow through the window (7443'-7455'). Window was clean--. After through the window, started pumping @ 345 gpm w/ 2900 psi. Rotated 60 rpm w/ 6000 ft Ib of tor ue. Ta ed bottom 7475'. 09:15 12:00 2.75 7,475 7,705 PROD2 DRILL DDRL P Directional drill "D" lateral. Max gas 60 units. 12:00 18:00 6.00 7,705 8,056 PROD2 DRILL DDRL P Directional drill "D" lateral. Max gas 25 units. 18:00 00:00 6.00 8,056 8,780 PROD2 DRILL DDRL P Directional drill "D" lateral. 06/12/2007 00:00 06:00 6.00 8,780 9,368 PROD2 DRILL DDRL P Directional drill "D" lateral. 06:00 12:00 6.00 9,368 10,211 PROD2 DRILL DDRL P Directional drill "D" lateral. Max gas 78 units. 12:00 18:00 6.00 10,211 11,065 PROD2 DRILL DDRL P Directional drill "D" lateral. Max gas 68 units. 18:00 22:15 4.25 11,065 11,447 PROD2 DRILL DDRL P Directional drill "D" lateral. 22:15 00:00 1.75 11,447 11,447 PROD2 DRILL OTHR T Attempt to orient Geopilot and change deflection from 69 deg. Change choke on geopilot skid from a 16 to a 28. Reboot surface and downhole computers. Try another mud pump. Send commands, wait on results. ~ ~ 06/13/2007 00:00 01:00 1.00 11,447 11,461 PROD2 DRILL OTHR T Attempt to orient Geopilot and change deflection from 69 deg. Change choke on geopilot skid from a 16 to a 28. Reboot surface and downhole computers. Try another mud pump. Send commands, wait on results. Directional drill "D" lateral. 01:00 06:00 5.00 11,461 8,527 PROD2 DRILL REAM T Backream out of the hole. Record PU and SO wYs every 5 stands in open hole. @ 11461': PU wt 170k, SO wt 80k, Rot 120 rpm w/ 6k ft Ibs of torque, 3300 psi. @ 9640': PU wt 160k, SO wt 85k, Rot 120 rpm w/ 5-6k ft Ibs of torque, 3240 si. 06:00 07:15 1.25 8,527 7,871 PROD2 DRILL REAM T Backream out of the hole. Record PU and SO wYs every 5 stands in open hole. 07:15 08:00 0.75 7,871 7,400 PROD2 DRILL TRIP T Pull out of the hole to above the window (TOW 7443'- BOW 7455'). PU wt 150k, SO wt 105k. 08:00 08:45 0.75 7,400 7,400 PROD2 DRILL CIRC T Establish circulation. Pump a 20 bbl weighted sweep (10 ppg/ 180 vis). Circulate 400 bbls total. Slight increase of cutting at the shakers. Max as 46 units. Cleanin ri floor. 08:45 09:00 0.25 7,400 7,400 PROD2 DRILL OWFF T Monitor well, OK. Continue cleaning ri floor. 09:00 09:30 0.50 7,400 7,400 PROD2 DRILL CIRC T Pump a 20 bbl dry job. Blow down top drive. 09:30 12:00 2.50 7,400 840 PROD2 DRILL TRIP T Continue to POOH w/ BHA #5 to change out 5200 series Sperry Sun GeoPilot TL 055. PU wt 145k, SO wt 105k. Record PU and SO wPs every 10 stands in cased hole. 12:00 13:00 1.00 840 0 PROD2 DRILL TRIP T Continue POOH. Record PU and SO wYs every 10 stands. PU wt 90k, SO wt 90k. Visual inspect GeoPilot, break off the bit. Calculated fill 46, actual fill 54.5 bbls. 13:00 13:45 0.75 0 91 PROD2 DRILL OTHR T Download MWD. 13:45 14:30 0.75 91 91 PROD2 DRILL PULD T Changeout the GeoPilot, make up same bit. 14:30 15:00 0.50 91 91 PROD2 DRILL OTHR T Upload MWD. 15:00 15:30 0.50 91 369 PROD2 DRILL CIRC T Trip in the hole. 15:30 16:00 0.50 369 369 PROD2 DRILL OTHR T Shallow pulse test MWD and res onse from GeoPilot. 16:00 16:30 0.50 369 369 PROD2 RIGMN SVRG P Service rig, drawworks, crown and blocks. 16:30 17:30 1.00 369 369 ~PROD2 RIGMN RGRP T Repair low lube pressure on top drive. • 06/13/2007 17:30 21:00 3.50 369 7,400 PROD2 DRILL TRIP T Trip in the hole w/ BHA #6. Record PU and SO wYs every 10 stands. Fill pipe every 25 stands. PU wt 102k, SO wt 100k. 21:00 22:15 1.25 7,400 7,400 PROD2 RIGMN SVRG P Change out the saver sub on the top drive. Change out gate, seat and bonnet to body "O" ring seal on 3" Demco valve used to isolate cement line on mud manifold. 22:15 23:45 1.50 7,400 7,400 PROD2 RIGMN RGRP T Electrician and crew change pressure indicator from gear oil pump to the PLC on the top drive. Monitor well on the tri tank. 23:45 00:00 0.25 7,400 7,495 PROD2 DRILL TRIP T Continue to trip in the hole w/ BHA #6. Record PU and SO wYs every 5 stands in open hole. Fill pipe every 25 stands. Rotate slow (30 rpm) to break in seals on the eo ilot. 06/14/2007 00:00 00:30 0.50 7,495 7,806 PROD2 DRILL TRIP T Trip in the hole w/ BHA #6. Tag up @ 7806'. 00:30 01:30 1.00 7,774 8,055 PROD2 DRILL REAM T Pick up and make a top drive connection. Ream f/ 7774' to 8055'. Rotate 50 rpm w/ 5000 ft Ibs of torque. Pum 240 m w/ 1640 si. 01:30 02:00 0.50 8,055 8,430 PROD2 DRILL REAM T Run 4 stands. Record PU and SO wYs eve 5 stands. 02:00 02:30 0.50 8,430 8,430 PROD2 DRILL TRIP T Circulate while backreaming f/ 8430' to 8340' and try to clean hole. Circulate 320 bbls. Shakers showed that the casing was dirty. Pumping 345 gpm w/ 3070 psi. Rotate 60 rpm w/ 5-6000 ft Ibs of torque. Initial ECD was 10.55 , final 10.36 02:30 02:45 0.25 8,430 8,711 PROD2 DRILL TRIP T Continue to trip in the hole w/ BHA #6. Ran 3 stands. 02:45 03:00 0.25 8,711 8,900 PROD2 DRILL REAM T Ream 2 stands in the hole. 03:00 04:30 1.50 8,900 10,960 PROD2 DRILL TRIP T RIH. Fill pipe @ 10776'. Record PU and SO wYs eve 5 stands. 04:30 05:15 0.75 10,960 11,461 PROD2 DRILL REAM T Ream in the hole to TD. Pumping 168 gpm w/ 1450 psi. Rotate 50 rpm w/ 6000 ft Ibs of tor ue. 05:15 06:00 0.75 11,461 11,546 PROD2 DRILL DDRL P Survey and orient GeoPilot. Directional drill "D" lateral w/ BHA #6. 06:00 11:00 5.00 11,546 12,261 PROD2 DRILL DDRL P Directional drill "D" lateral. Max gas 43 units. 11:00 12:45 1.75 12,261 12,261 PROD2 DRILL CIRC P Take final survey @ TD. Acquire ~ SPR's. Pump a 30 bbls weighted high vis sweep (10 ppg/ 220 vis). Rotate 120 rpm w/ 7-8k ft Ibs of torque. Rot wt 118k. Pumpng 345 gpm w/ 3750 psi. Reciprocate f/ 12261' to 12180'. ECD's 11.76 ppg. Pump a total of 608 bbls. Slight increase in cuttin s. 12:45 13:00 025 12,261 12,261 PROD2 DRILL OWFF P Monitor well for flow, OK. ~ 06/14/2007 13:00 18:00 5.00 12,261 9,558 PROD2 DRILL REAM P Backream out of the hole. Rotate 120 rpm w/ 6-7k ft Ibs of torque. Pumping 345 gpm w/ 3700 initial to final of 3150 psi @ 9558'. Record ECD's every 10 stands ECD of 10.71 ppg @ 9558'. SLM. 18:00 21:00 3.00 9,558 7,586 PROD2 DRILL REAM P Backream out of the hole. Rotate 120 rpm w/ 7-5k ft Ibs of torque. Pumping 345 gpm w/ 3150 initial to final of 2920 psi @ 8246'. Record ECD's every 10 stands. SLM. 21:00 21:30 0.50 7,586 7,401 PROD2 DRILL TRIP P POOH on elevatros through the window (TOW 7443', BOW 7455') to 7401'. Note: Calculated fill 27 bbls, actual fill 28 bbls. SLM. 21:30 23:30 2.00 7,401 7,401 PROD2 DRILL CIRC P Circulate to clean up cuttings inside of the 7-5/8" casing. Pump a 41 bbls weighted hi vis sweep (10 ppg/ 190 vis). Cire sweep surface to surface + 3 BU. Reciprocate from 7401' to 7307'. Rotate 120 rpm w/ 4-5k ft Ibs of torque. Pumping 350 gpm w/ 2870 psi. Initial ECD was 10.12 ppg, final 9.99 23:30 00:00 0.50 7,401 8,243 PROD2 DRILL TRIP P Trip in the hole on elevators. 06/15/2007 00:00 02:00 2.00 8,243 12,178 PROD2 DRILL TRIP P Trip in the hole on elevators. 02:00 06:30 4.50 12,178 12,261 PROD2 DRILL CIRC P Make a top drive connection. Rotate 120 rpm w/ 7-8k ft Ibs. Pumping 345 gpm w/ 3700 psi. Reciprocate f/ 12175' to 12261'. Pump a weighted hi vis sweep (10 ppg/ 200 vis) surface to surface + 4 BU.Initial ECD's were 11.36 ppg, final 11.2 ppg. Hold PJSM on displacement to 8.4 ppg solids free oil base mud. Circulated a total of 1762 bbis. 06:30 07:45 1.25 12,261 12,261 PROD2 DRILL CIRC P Displace f/ 8.4+ MOBM to 8.4 ppg SFOBM. Rotating 120 gpm w/ 7-8k ft Ibs of torque. Pumping 345 gpm w/ 3830 si. Rotatin wt 125k. 07:45 08:00 0.25 12,261 12,261 PROD2 DRILL OWFF P Observe well for flow. Ok. 08:00 08:15 0.25 12,261 12,261 PROD2 DRILL SFTY P PJSM on tripping out of the hole. 08:15 09:00 0.75 12,261 11,244 PROD2 DRILL TRIP P Pull out of the hole on elevators, wet. 09:00 09:15 0.25 11,244 11,244 PROD2 DRILL CIRC P Pump a 19 bbl dry job (mixed powder calcium chloride) , chase w/ 10 bbls. 9.7 ppg/70 vis. Pumping 162 gpm w/ 1000 si. 09:15 12:00 2.75 11,244 7,401 PROD2 DRILL TRIP P Trip out w/ BHA #6. Dropped a 1-7/8" rabbit w/ bit 9933'. 12:00 12:15 0.25 7,401 7,401 PROD2 DRILL OWFF P Observe well for flow. OK. . 06/15/2007 12:15 16:45 4.50 7,401 371 PROD2 DRILL TRIP P Continue POOH w/ BHA #6. Found 1-7/8" rabbit on the ~ars. 16:45 17:00 0.25 371 371 PROD2 DRILL SFTY P PJSM on laying down BHA #6. 17:00 17:45 0.75 371 91 PROD2 DRILL PULD P UD BHA #6. Note: Calculated fill 71.7 bbls,actual 80.5 bbls at 1800 hrs. 17:45 18:15 0.50 91 91 PROD2 DRILL OTHR P Download Sperry Sun MWD. 18:15 18:45 0.50 91 0 PROD2 DRILL PULD P Finish laying down BHA #6. 18:45 19:15 0.50 0 0 PROD2 DRILL PULD P Lay down subs and equipment f/ BHA #6. Clear floor. Shut blind rams. 19:15 19:45 0.50 0 0 COMPZ CASINC RURD P Rig up to run 4-1/2" slotted liner. 19:45 20:00 0.25 0 0 COMPZ CASINC SFTY P PJSM on running "D" lateral 4-1/2" sloUblank liner 11.6 f. 20:00 21:45 1.75 0 4,549 COMPZ CASINC RNCS P PU/MU "D" lateral 4-1/2" 11.6 ppf L-80 BTC slot/blank liner. 21:45 22:00 0.25 4,549 4,616 COMPZ CASIN( RNCS P MU 5-1/2" Recepticle joint and Baker liner settin sleeve. 22:00 22:30 0.50 4,616 4,616 COMPZ CASIN( RURD P Clean and clear floor. UD GBR casing runnin tools. 22:30 00:00 1.50 4,616 5,650 COMPZ CASIN RUNL P RIH w/ liner on 4" drill string. 4 stands of slick drill pipe, then will run 40 stands of 4" drill pipe w/ super sliders. 11 total stands in the hole @ midni ht. 06/16/2007 00:00 05:00 5.00 5,650 12,193 COMPZ CASIN RUNL P RIH w/ liner on 4" drill string. 4 stands of slick drill pipe, then 40 stands of 4" drill pipe w/ super sliders, then 16 stands of slick drill pipe, 4 stands of 4" HWDP, 15 stands of hybrids (2 jts of 5" DC's & 1 jt 4" HWDP), then 3 stands of slick 4" drill pipe. Record PU and SO and rotating weighYs and torque according to Rig Engineer's directions. PU wt 215 to 220k, SO wt 80k, Rotating wt 140k, rotating torque 9500 ft Ibs. 05:00 05:30 0.50 12,193 12,251 COMPZ CASINC RUNL P Make top drive connection on stand 82. Rotate 30' in the hole w/ 30 rpm and 9500 ft bls of torque. PU wt 215k, SO wt 85k. Continue in hole, tag bottom 4' deep @ 12265'. Pickup and position top of liner @ 7640.46' (shoe 12251'. 05:30 06:00 0.50 12,251 7,606 COMPZ CASINC OTHR P Break a single, drop a 29/32" ball. Pump ball down @ 3 bpm w/ 550 psi. Ball on seat with 652 strokes pumped. Pressure to 3000 psi to release liner, slack off, PU and observe PU wt to be 190K, SO observed to be 122k. Pressure to 4150 to shear circutating sub.Pull stand #82 out of the hole. PU wt 190k. SO wt 122k. • 06/16/2007 06:00 06:15 025 7,606 7,420 COMPZ CASIN OTHR P POOH to get inner above window. PU wt 180k, SO wt 122k. 06:15 07:00 0.75 7,420 7,420 COMPZ CASIN( CIRC P Circulate bottom's up x2. Circulate a total of 573 bbls. 07:00 07:30 0.50 7,420 7,420 COMPZ CASIN OTHR P Observe well for flow. Prepare to POOH. 07:30 07:45 025 7,420 7,420 COMPZ CASIN( CIRC P Pump a 9 bbl dry job (9.4 ppg 57 vis) 07:45 12:15 4.50 7,420 30 COMPZ CASIN OTHR P POOH w/ baker HR running tools and inner string. Record PU and SO wt's eve 10 stands. 12:15 12:45 0.50 30 0 COMPZ CASINC OTHR P Lay down Baker inner string and runnin tools. Lost 8 bbls on tri out. 12:45 13:30 0.75 0 337 COMPZ FISH PULD P PU/MU Baker fishing assembly to retrieve the whipstock for the "D" lateral. 13:30 17:00 3.50 337 7,386 COMPZ FISH TRIP P Trip in the hole w/ retrieving hook assembly. Lost 8 bbls while trip in the hole. 17:00 17:30 0.50 7,386 7,410 COMPZ FISH FISH P Establish circulation. Pumping 3 bpm w/ 700 psi. Five foot in from 7386' to 7448'. Hook the slot. PU wt 185k, SO wt 125k. Slack off to 100k and cock the jars. Pull to 240k, slack off to 100k, pull to 250k, then pull free to 7410' w/ 192k u wt. 17:30 18:30 1.00 7,410 7,410 COMPZ FISH CIRC P Circulate BU. Pumping 210 gpm w/ 1130 psi. Circulate a total of 241 bbls. Lost 10 bbls while circulatin . 18:30 18:45 0.25 7,410 7,410 COMPZ FISH OTHR P Monitor well for flow. Prepare f/ trip out of the hole with the whipstock assembly that was run for the "D" lateral. 18:45 23:00 4.25 7,410 157 COMPZ FISH TRIP P POOH w/ whipstock assembly. Pullin carefull . 23:00 23:30 0.50 157 97 COMPZ FISH PULD P Lay down BAKER fishing assembly 23:30 23:45 0.25 97 97 COMPZ FISH SFTY P PJSM on laying down whipstock assembl . 23:45 00:00 0.25 97 77 COMPZ FISH PULD Laying down whipstock assembly. Lost 6 bbls on tri out. 77 COMPZ FISH Total fluid lost to hole is 32 bbls. 06/17l2007 00:00 00:30 0.50 77 0 COMPZ FISH PULD P Lay down whipstock assembly. Note: as stated in yesterdays report, fluid loss on trip is 6 bbls: calc 55 bbls, actual 61 bbls. 00:30 00:45 0.25 0 0 COMPZ FISH OTHR P Clear and clean rig floor. 00:45 01:15 0.50 0 0 COMPZ CASIN PUTB P PU Sperry Sun super slim MWD. Break flow tube to the collar. Lay down to the i e shed to install ulsar. 01:15 01:45 0.50 0 0 COMPZ CASINC OTHR P Clear Baker whipstock tools from floor. Clean floor. RU 01:45 03:00 1.25 0 0 ICOMPZ CASINf RURD P Rig up to run Hook Hanger f/ "D" lateral. ~ 06/17/2007 03:00 03:15 0.25 0 0 COMPZ CASINC SFTY P PJSM on running Baker Hook Hanger. 03:15 04:00 0.75 0 213 COMPZ CASINC RNCS P MU Hook Hanger assembly to 213'. 04:00 04:30 0.50 213 213 COMPZ CASIN OTHR P RU/MU inner string w/ MWD f/ hook han er. 04:30 05:00 0.50 213 213 COMPZ CASIN( OTHR P Change elevators to PU HH and orient same to MWD. MWD oriented 54.22 deg left of highside-- 180 deg from hook o enin . 05:00 05:15 0.25 213 213 COMPZ CASIN( OTHR P Test MWD w/ 126 gpm w/ 640 psi. 05:15 06:00 0.75 213 966 COMPZ CASIN( RUNL P RIH w/ Hook Hanger on 4" drill string to 966'. 06:00 06:15 0.25 966 966 COMPZ CASIN( OTHR P Re-arrange stabrite service loop out of the wa of the to drive service loo . 06:15 11:00 4.75 966 7,637 COMPZ CASIN RUNL P RIH w/ Hook hanger on 4" drill string. Fill string and test MWD every 25 stands. Note: 2596':Pumping 130 gpm w/ 790 psi. Good toolface. Also @ 4941' -890 si, PU wt 190k, SO wt 125k. 11:00 13:45 2.75 7,637 7,567 COMPZ CASINC OTHR P Pumping @ 7649' w/ 130 gpm and 1000 psi. PU wt 190k, SO wt 120k. Orient 16 left, five foot in to 7679' bottom of mule shoe. Hook and siack off 20k. Hook @ 4 left. PU and orient 180 right, slack off to 7684' (5' below being hooked). PU 20' and orient set down and hook. Hooked a couple of times @ 42' (4 deg ieft) and set 35k down. Drop .90 ball,circ down @ 3bpm w/ 1020 psi, ball on seat w/ 65 bbis pumped. Pressure up to 2000 psi. Zero stoke counter, stage pumps up in 200 psi increments. Release running tool. Shear valve in ECP with 2340 psi, inflate ECP w/ 3 strokes. Final pressure 2300 psi. Bleed off pressure. Pressure to 4150 psi and shear ball seat. With tool releasee PU with inner string swabbing until above hook hanger. Picked up 70'. Note:Found BOW 1' dee 7456'. 13:45 15:00 1.25 7,567 5,789 COMPZ CASIN( OTHR P Pull out of the hole. Stand back 4 stands of HWDP and 15 stands ofH brids 15:00 16:15 1.25 5,789 5,789 COMPZ RIGMN' SVRG P Slip and cut 129' of 1-3/8" drilling line. 16:15 17:00 0.75 5,789 5,789 COMPZ RIGMN SVRG P Inspect drawworks and grease same. Grease traveling equipment and top drive. 17:00 18:00 1.00 5,789 5,373 COMPZ CASINC OTHR P Pull out of the hole laying down 4" drill string. Dropped Haggard ID wiper. Remove and inspect VWVf super sliders. ~ 06/17/2007 18:00 00:00 6.00 5,373 1,690 COMPZ CASIN OTHR P Continue POOH laying down Weatherford 4" drill pipe. Remove and inspect VWVf super sliders. Note: 42 super sliders still in the hole @ midni ht. 06/18/2007 00:00 01:00 1.00 1,690 132 COMPZ CASIN( OTHR P Continue POOH laying down Weatherford 4" drill pipe. Remove and inspect UWVf super sliders. Note: 42 super sliders still in the hole @ midni ht. 01:00 01:45 0.75 132 132 COMPZ CASIN OTHR P Remove super sliders from the floor. RU to laydown Baker Hook Hanger running tools and inner string w/ S er Sun MWD. 01:45 02:45 1.00 132 0 COMPZ CASIN OTHR P Make service breaks and lay down runnin tool and inner strin . 02:45 03:15 0.50 0 0 COMPZ CASIN OTHR P Lay down handling tools, clear rig floor. 03:15 03:45 0.50 0 0 COMPZ DRILL OTHR P Bring XT39 thread protectors to the floor. Pull mousehole, ptug bottom, install in the rotary table for laying down drill i e from the derrick. 03:45 04:00 0.25 0 0 COMPZ DRILL SFTY P PJSM on laying down 67 stands of 4" dp, 4 stands of 4" HWDP and 15 stands of hybrids from the derrick. Monitor well on tri tank. 04:00 06:00 2.00 0 0 COMPZ DRILL PULD P Lay down 37 stands of 4" dp from derrick. 06:00 06:15 0.25 0 0 COMPZ DRILL SFTY P PJSM on laying down dp f/ derrick. 06:15 11:00 4.75 0 0 COMPZ DRILL PULD P Lay down 30 stands of 4" dp, 4 stands of HWDP and 15 stands of hybrids from derrick. down). Monitor well on tri tank. 11:00 11:30 0.50 0 0 COMPZ DRILL OTHR P Pull mousehole from rotary table. Clean and clear ri floor. 11:30 12:00 0.50 0 0 COMPZ RPCOh RURD P RU to run 4-1/2" 12.6 ppf16T-m L-80 tubin . 12:00 14:30 2.50 0 1,920 COMPZ RPCOti RCST P Make up perforated bull nose shoe to catch Haggard ID wiper, continue PU/MU/RIH 4-1/2" tubin . 14:30 17:30 3.00 1,920 1,920 COMPZ RIGMN RGRP P Trouble shoot and repair pipe handiing machine. 17:30 21:45 4.25 1,920 7,004 COMPZ RPCO RCST P Continue trip in the hole w/ 4-1/2" 12.6 ppf IBT-m L-80 completion tubing. Ran in with a total of 228 'oints. 21:45 22:15 0.50 7,004 7,004 COMPZ RPCOh SFTY P Pre job safety meeting on POOH, standing back 4-1/2" tubing f/ the ESP com letion. 22:15 00:00 1.75 7,004 3,300 COMPZ RPCOh TRIP P POOH standing back 4-1/2" completion tubing. PU wt 122k, So wt 95k. 06/19/2007 00:00 03:00 3.00 3,300 0 COMPZ RPCOh TRIP P POOH standing back 4-1l2" com letion tubin . 03:00 03:30 0.50 0 0 ICOMPZ RPCOh OTHR P Pull Vetco Gray wear bushing. Clean floor. • 06/19/2007 03:30 04:30 1.00 0 0 COMPZ RPCO PULD P Pickup Centralift equipment to the floor. RU. 04:30 04:45 0.25 0 0 COMPZ RPCOh SFTY P Pre job safety meeting on Picking up first componets of completion, setting um with Halliburton wireline. 04:45 05:30 0.75 0 85 COMPZ RPCO PULD P MU/RIH perforated crossoverwith pup, 2 joints of 4-1/2" 12.6 ppf IBT-m L-80 tubing, 4-1/2" pup jt, Unique discharge sub, and 4-1/2" u 't. 05:30 05:45 0.25 85 85 COMPZ RPCO PULD P PU Pump. Set pump eye, gas seperator, and high volume middle tandem pump inside the 4-1/2" tubing the rota table. 05:45 06:00 0.25 85 85 COMPZ RPCOa RURD P RU Halliburton slickline. Crew Change 06:00 06:30 0.50 85 85 COMPZ RPCOh OTHR P Make up pump sections, lower into 4-1/2" tb . 06:30 06:45 0.25 85 85 COMPZ RPCOh PULD P Halliburton wireline test fit D&D stinger, 2-7/8" Dart check valve, 2-7/8" spacer pipe Kobe Knock out, D& D packoff assembly. Cheveron seals messed u. Chan e out seals. 06:45 07:15 0.50 85 85 COMPZ RPCOh OTHR P Lower pump assembly with wireline. 07:15 08:30 1.25 85 85 COMPZ RPCOh OTHR P Halliburton wireline run the D&D stinger, 2-7/8" Dart check valve, 2-7/8" spacer pipe Kobe Knock out, D& D packoff assembly. Fill tubing. Test to 1000 psi f/ 15 min. Set Slip stop. Monitor well. 08:30 08:45 0.25 85 85 COMPZ RPCOh OTHR P RD halliburton Slickline unit. 08:45 12:00 3.25 85 85 COMPZ RPCOh PULD P Make up motor, Upper & lower tandem, Check rotation of motor & pump components with tubing crossover.Good free movement.Fill Motor, and seal sections. Fill Bearing XO. Attach ESP cable & control line. Perform olarit test. 12:00 14:30 2.50 85 85 COMPZ RPCOh PULD P Continue fill Motor, and seal sections. Fill Bearing XO. Attach ESP cable & control line. Perform polarity test. Monitor well through trip tank. No losses. 14:30 18:00 3.50 85 3,290 COMPZ RPCOh RCST P Held PJSM with crew & Baker reps.Discuss safety & hazard recognition issues. Discuss running procedure,and positioning of clamps. Trip in hole with 4 1/2" production tubing installing Cannon Clamps on every collar. Perform megger test every 10 stands. Run to 3290'. Record T&D parameters as per rig engineer. Observed proper dis~lacement in hole. Crew chanae • 06/19/2007 18:00 22:45 4.75 3,290 7,200 COMPZ RPCOh RCST P Continue trip in hole with 4 1/2" production tubing from 3290' - 7231' installing Cannon Clamps on every collar. Perform megger test every 10 stands. record T&D parameters as per rig engineer. Observed proper dis lacement in hole. 22:45 23:15 0.50 7,200 7,200 COMPZ RPCOti RCST P Make up vetco gray hanger with landin 'oint. 23:15 00:00 0.75 7,200 7,200 COMPZ RPCOh OTHR P Install penetrator sub in hanger. Rig up to splice ESP cable as per Weatherford, and Baker re s. 06/20/2007 00:00 05:30 5.50 7,200 7,200 COMPZ RPCOti OTHR P Slice ESP cable as per Baker centrilift rep. Attach ESP cable to pentrator, and clamp off same. Simops: Clean drip pan, Clean & clear floor of tools and euipment. prep cellar for nipple down. Perform Derrick Ins ection. 05:30 06:00 0.50 7,200 7,200 COMPZ RPCOh RCST P Perform Megger test on ESP line before landing hanger. Drain BOP Stack, Blow down lines. Crew Chan e 06:00 07:00 1.00 7,200 7,231 COMPZ RPCOh RCST P Land Tubing hanger on depth, and RILDS. UP WT = 140K, SO WT = 100K. Rig up, test upper & lower seals as per Vetco Gray rep to 5000 PSI. Back out & la down landin 'oint. 07:00 07:15 0.25 7,231 7,231 COMPZ RPCOh OTHR P Install BPV. 07:15 12:00 4.75 0 0 COMPZ RPCOh NUND P Finish blow down all lines. Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss Nippie down BOP's. Nipple down BOP stack & lines. 12:00 14:30 2.50 0 0 COMPZ RPCO NUND P Nipple up Vetco Gray 5K Tree. Make up Lubricator. Pull BPV. Install TWC. Test void to 5000 PSI - 10 minutes. Fill tree with Diesel and test tree to 5000 PSI - 10 Minutes. pull TWC with Lubricator. SIMOPS: RU Little Red Services. Rig down Mudline & secondary Kill @ Pits / Sub i ntercon nect. 14:30 15:00 0.50 0 0 COMPZ RPCOti SFTY P Held PJSM with crew & Little Red reps. Discuss safety & hazard recognition issues. Discuss freeze protect procedure. Designate Spill / / i 06/20/2007 15:00 18:00 3.00 0 0 COMPZ RPCOh FRZP P With Litle Red. test lines to 1000 PSI. ICP - 1 BPM - 200 PSI. Attempt to pump at higher rate observing fluid losses 20-40%. Continue maintain 1 BPM rate obtaining 1 for 1 returns pumping down annulus with pump pressure @ 475 PSI. Prepare rig floor for Skid, Shut down air, water, and steam to rig floor. Prep cellar for move. Lowwer strongbacks in pipe shed for floor skid. Note: Rig off of Hiline power 1540 HRS. Crew Chan e 18:00 20:30 2.50 0 0 COMPZ RPCOI~ FRZP P Continue pumping down annulus at 1 BPM with no losses. Pump pressure 475 - 500 PSI. Pump a total of 360 BBLS observing 6.9 PPG diesel returns with FCP - 2 BPM - 575 PSI. Shut in well. Record shut in pressure at OA = 120 PSI, IA = 350 PSI, & tubin at 350 PSI. 20:30 21:00 0.50 0 0 COMPZ RPCOti OTHR P Secure well. Rig down Little Red Services. Blow down, and rig down lines. Blow down Poorboy Degasser, flush same. Clean its. 21:00 22:00 1.00 0 0 COMPZ RPCOh OTHR P With lubricator. Install BPV as per Vetco rep. Rig down Lubricator. remove secondary annulus valves. install Com anion flan es & valves. 22:00 00:00 2.00 0 0 DEMOB MOVE DMOB P Clean pits. Skid rig floor. Disconnect water, air, Hydraulic, and steam lines. Prep Pits, and sub complex for move. Rig released at Midnight for summer maintenance. - ~ ~ ~ Slotted and Blank LinerDetail weu: ~~-~5s ConocoPhillips 4-~~z" 11.6# L-80 BTC Date: 6/1 612 0 0 7 ataska,ina "~° I8t@C8I II11@C Rig: Doyonl5 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN OD(in) Max OD(in) ID(in) LENGTH TOPS Pape 1., nominal actual actual Drill i e needed 7631.05 XO 4.5" XT39 x 3-1/2" IF 2.99 7631.05 Baker Liner settin tool with u't 6.42 7634.04 HR Liner Setting Sleeve w/ 10' TBR 5.5" ( 6.43" OD x 5.01" ID ) 5.5 6.43 5.01 12.71 7640.46 Liner Pup Jt 5.5" 15.5# L80 5.5"Hyd 521 p X p( 5.54" OD x 4.89'9D) 5.5 5.54 4.s9 7.43 7653.17 Receptacle Jt 5.5" 15.51/ L80 5.5" Hdy 521 b X p( 5.73" OD xID 4.94") 5.5 5.73 4.94 36.32 7660.60 XO Swb 5.5"H d 521 X 4.5"BTC 5.73"OD X 3.93" ID 5:5 5.73 3.93 1.40 7696.92 4-1l2" 8TC-m 12.6 ppf, L-80 Pup joint (5.02" OD z 3.91" ID 4.5 5.02 3.99 3.82 7698.32 Jts 85 to 105 21 Jts 4-1/2" BTC wITQ Rin s 11.6. p f, L-80 Slotted Casin a.s s a 906.15 7702.14 Jts 78 to 84 7 Jts 4-1/2" BTC w%TQ Rin s 11.6 ppf, L-80 * 7 Blanks a.s 5 a 299.71 8608.29 Jts 55 to 77 23 ~ts 4-1I2" BTC wITQ Rin s 11.6 f, L-80 Slotted Casin a.s s a 983:78 8908.00 Jts 27 to 54 2s ~ts 4-1/2`' BTC 11.6 ppf, L-80 Slotted Casin a.s 5 4 1195.86 9891.78 ~ts za to 2s 3,lts 4-1/2" BTC 11.6 f, L-80 * 3 Blanks a.s 5 a 128.45 11087.64 Jts 1 to 23 23 Jts 4-1/2" BTC 11.6 p f, L-80 Slotted Casin a.s 5 a 990.17 11216.09 41/2", 11.6 ppf, L-80, BTC Blank Casing(5.0" OD x 4" ID) a.5 5 a 43,.06 12206.26 ROT Silver Bullet Guide Shoe No float 5.02" OD a.s s.o2 1.68 12249.32 Bttm of Shoe =_> 12251.00 12251.OQ Note; Top "D" Lat. window 7443' MD/ 3250' ND 12251.00 Bttm of window 7455' MD 133252' TVD 12251.00 Window 80.27 De . 12251.00 12251.00' To~ o# ~ lat liner to packer 7541.41' 1V1D 12251.00 3249' TVD 80.27 de 12251.00 ~ Liner RS Sea! Nip~le !D 4.88°' 7560° NED 12251.00 3269° TdD 80.69 eleg 12251.00 S Liner XO sa~b ID 3.92" 7593' MD 12251.00 3274.38° 7VD 8a.45 de 12251.00 TD 6-3/4" hole 12261' MD / 3236.41' TVD 12251.00 4-1/2" Shoe 12251' MD / 3236.21' TVD / 88.84 De . 12251.00 Liner set 10' from bottom. 12251.00 ~un 105 h droforms 8Q590- 3 rib 1 H draform per ji._ 12251.00 on joints #1 thru Jts #105. No stops were run. 12251.00 Run torque rin s in the top 51 'ts of the BTC-M liner. 12251.00 Jts # 55 thru Jt# 105= 2189.44' 12251.00 Run Slots: 95 j ts BTC = 4075.96', Run 8lanks: 'l O jts BTC = 428.16' + shoe jt 44.74'. U Wt 215k Slots are 0.125" wide x 2.5" long x 32 slo/ft. w/ (32) 2.5" long x.125" @ 4 Dn Wt 85k Circumferential adjacent rows, 3" Centers staggered 18 deg. 3' non-slotted ends. Block Wt 70k Torqued BTC liner w/o torque rings to 2800 ft-Ibs, w/ torque rings to 5000 ft-Ibs, Hyd 521 to 5500 ft-Ibs Used Run-N-Seal thread compound on all connections. Allydrifted w/ 3.875" rabbit. Supervisors: Fred Herbert / Granville Rizek .3 ~ ~ ~fi~ ~ ~ °~ ,~ ~~°~. $.~.._~ ~ _. ~_~ ~~ ~._,~ a ~ ~.. ~ n ~~~ ~ ~p ~~ ~ ~ ' ~ ,i .'~~ ~ ~ ~ ~ ~~~~ " ~` ~~~~ ~ ~ ~~ ~ ~- ~ ~ ~.~ ~ ~ ATsA-58i11 OIL A1~TD (i~-S COI~TSER~ATI011T COl-i1~II5SI0I~T Randy Thomas Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-158L 1 ConocoPhillips Alaska, Inc. Permit No: 207-055 Surface Location: 2056' FSL, 2250' FEL, SEC. 35, T11N, R10E, UM Bottomhole Location: 1533' FSL, 1865' FEL, SEC. 3, T10N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 1J-158, Permit No 207- 054, API 50-029-23356-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). incerely, /~~ Dan T. Seamount Commissioner DATED this 3 ~ day of April, 2007 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ STATEOFALASKA ~ ~~'~'"~~~~D ALASKA OIL AND GAS CONSERVATION COMMISSION Ap R 2 5 2007 PERMIT TO DRILL ~/~ 20 AAC 25.005 ~i~~ka ~~1 g~ Gas Cons. Comm+ssion 1a. Type of Work: 1b. Current Well Class: Exploratory ~ Development Oil Q e 1c. Speciry if well is pro . Drill Q' Re-dritl Strat+graphic Test ^ Service ^ Development Gas ~ Coalbed Methane ^ Gas Hydrates ^ Re-entry ^ Multiple Zone^ Single Zone ~ Shale Gas ^ 2. Operator Name: 5. Bond: / Blanket Single Well 11. Well Name and Number: ConocoPhillipsAlaska, Inc. Bond No. 59-52-180 - 1J-158L1 ~ 3. Address: 6. Proposed Depth: 12. Field/Pool(S): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 12225' ~ ND: 3228' ' Kuparuk River Field 4a. Location of Well (Govemmental Section): 7. Property Designation: Surface: 2056' FSL, 2550' FEL, Sec. 35, T11N, R10E, UM ' ADL 25660, 25667, 25663 ~ West Sak Oil Pool ~ Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1000' FSL, 2236' FEL, Sec. 34, T11 N, R10E, UM ` ALK 470, 471, 472 5/20/2007 Total Depth: 9. Acres in Property: 14. Distance to 1533' FSL, 1865' FEL, Sec. 3, T10N, R10E, UM ' 2560 Nearest Property: < 1 mile - 4b. Location of Well (State Ba Plane Coordinates): 10. KB Elevation ~` j°~~~. lt± ar c l 15. Distance to Nearest ~ ~ Surface: x- 558659 y- 5945867 Zone- 4 v~ o (Height above GL): 4O' RKB feet N/ell within Pool: 1J-168L2 , 1024' ' 16. Deviated wells: Kickoff depth: 7449 E ft. 17. Maximum Anticipated Pressures in psig (see 2o AAC 25.035) Maximum Hole Angle: 95.5° deg Downhole: 1531 psig ~ Surface: 1173 psig ' 18. Casing Program S if ti Setting Depth Quantity of Cement Si peC iCa OnS T B tt ze om op o c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 42" 20"x34" 94# K-55 Welded 80' 28' 28' 121' - 121' • 260 cf ArcticCrete 13.5" 10.75" 45.5# L-80 BTC 3393' 28' 28' 3393' , 2152' 590 sx AS Lite, 180 sx DeepCRETE 9.875" 7.625" 29.7# L-80 BTCM 8023' 28' 28' 8023' ~ 3324' ~ 380 sx DeepCrete 6.75" 4.5" 11.6# L-80 BTC .~9'' 7449' 3250' 12225', 3228' - slotted Iiner '~''tl. 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD ND ConductodStructural Surface Intermediate Production Liner Perforation Depth ND (ft): Perforation Depth MD (ft): 'D G~ I 20. Attachments: Filing Fee L BOP Sketch ~ Drilling Program O Time v. Depth Plot Shallow Hazard Analysis ~ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ~/ 20 AAC 25,050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. ContBCt Dennis Haltwig @ 265-6862 Printed Name Randy Thomas ritie Drilling Team Leader Signature ~y "'~`~~~ Phone ~6S-`,~~~ Date ~~~~L4'~~~) h n Dra Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: ~~ -~i j 5~ 50- ~i' ~-~- ~, .~ j5 ~"~: Date: ~~''~ for other requirements Conditi0ns Of app~OVal : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: ° Samples req'd: Yes ^ No ~ Mud log req'd: Yes ^ No [~ Other: ~~~ ~S`~ ~P ~~ H2S measures: Yes ~ No [~' Directional svy req'd: Yes [~ No ^ P OVED BY THE COMMISSION DATE: , COMMISSIONER Form 10-401 Revised 12/2005 /1/ _~ Submit in Duplicate ~//~"r 7~~~/7,?S~ G~. 2 7., v`7 /'- . ~ Ap~ion for Permit to Drill, Well 1 J-158L1 Revision No.O e.,.,e.~. ~a n... m Permit It - West Sak Well #1J-158 L1 Producer ~~°~ r.w ~~k Application for Permit to Drill Document ~-~•~ ~ ~3 ~~~~ w~t- valu~ Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (fl ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) ........................:......................................................................... 3 6. Casing and Cementing Program ............................................................................ 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 Surface Hole Mud Program (extended bentonite) .................................. Error! Bookmark not defined. Intermediate Hole Mud Program (LSND or MI VersaPro Mineral OilBase)Error! Bookmark not defined. Lateral Mud Program (MI VersaPro Mineral OilBase) ...........................................................:............... 4 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9J .................................................................................................. 5 10. Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 1J-158L1 PERMIT/T Page 1 of 6 Pnnted: 16-Apr-07 ~ t ~~~ t~ r l~ ~ Appl~n for Permit to Drill, Well 1 J-158L1 Revision No.O Saved: 16-Apr-07 12. Evidence of Bonding ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 13. Proposed Drilling Program ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 14.Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments ............................................................................................................. 6 Attachment 1 Directional Plan ................................................................................................................ 6 Attachment 2 Drilling Hazards Summary ............................................... Error! Bookmark not defined. Attachment 3 Well Schematic ............................................................................................................... 6 1. Well Name Requirements of 20 AAC 25.005 (~ Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding ~~ su~x to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1J-158 Li. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates ~~f the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (e) the coordinates of the proposed location of the well aY the surface, referenced to the state plane coordinate system for thrs state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the,proposed depth of the well at the top of each objective formation and at total depth; Location at SurFace 2 056` FSL 2 550' FEL Section 35 T11N R10E ASP Zone 4 NAD 27 Coordinates RKB El2Vdi7017 121.0' AMSL Northings: 5,945,867 Eastings: 558,659 Pad Elevation 81.0' AMSL Location at Top of Productive Interval West Sak "D" Sand 1000' FSL, 2,236' FEL, Section 34, T11N, R10E ., ASP Zone 4 NAD 27 Coordinates Measured De th RKB: 7 449 Northings: 5,944,775 Eastings: 553,703 Total Vertical De th, RKB: 3,250 Total Vertical De th SS: 3,129 Location at Total De th 1533` FSL 1 865' FEL Section 03 T10N R10E ASP Zone 4 NAD 27 Coordinates Measured De th RKB: 12, 225 Northings: 5,940,031 Eastings: 554,116 Total Vertical De th, RKB: 3,228 Total Vertical De th, SS: 3 106 and (D) other information required by 20 AAC 25.050(b); 1J-158L1 PERMIT IT Page 2 of 6 Printed: 16-Apr-07 ~~~~~€~~~~ ~ Ap~on for Permit to Drill, Weli 1J-158L1 Revision No.O Saved: 16-Apr-07 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a plat drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in pub(ic records, and show that each named operator has been furnished a copy of the application by certified mail; or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or ZO AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-158 L1. Please see information on Doyon 15 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, induding (A) the maximum downhole pressure that may be encountered, criterra used to determine it, and maximum potential surface pressure based on a methane gradient~ ~ The expected reservoir pressures in the West Sak sands in the 1] area vary from 0.44 to 0.47 psi/ft, or 8.5 to 9.0 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from Nearby West Sak wells The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak D sand formation is 1,173 psi, calculated thusly: MPSP =(3,257 ft ND)(0.47 - 0.11 psi/ft) = 1,173 psi ~ (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. ' and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: 1J-158 Ll Drilling Hazards Summary. ~ 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identrfied in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(~; The parent wellbore,iJ-158 will be completed withJ-5/8" intermediate casing land~d at the top of the West Sak B sand. The casing shoe will be drilled out and a formation integrity test will be performed in ~RIGI~~L 1J-158L1 PERM/T IT Page 3 of 6 Printed: 16 Apr-07 C~ Appl~n for Permit to Drill, Well 1 J-158L1 Revision No.O Saved: 16-Apr-07 accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Ho/e Top Btm Csg/Tbg Size Weigh Length MD/7VD MD/TVD OD in in t/b/ft Grade Connection (ft) ft (ft) Cement Pro ram 4-1/2 6-3/4" D Sand 11.6 L-80 BTC 4,776 7,449 / 12,225 / 3,228 Slotted- no cement SlOtted ~teral (iJ-158 Ll) 3,250 4 1/2 NA 12.6 L-80 IBTM 7,350 28 /28 7,350 / 3,110 Production Tubing tubin # 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is warved by the commission under ZO AAC 25.035(h)(2); No diverter system will be utilized during operations on 1J-158 Li. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on fle with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro Mineral Oil Base) A/B/D sand laterals Value Density (ppg) $•4 or as needed Plastic Viscostiy 12 - 19 Ib/100 sf Yield Point ~ $ _ 28 (cP Oil / Water Ratio 80 / 20 Electrical >600 Stabilit ~ Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 15. 1J-158L1 PERM/T/T Page 4 of 6 ~ ~ ~ ~ ~ 9 ~ y~ ~ Printed: 16-Apr-07 ~ Ap~on for Permit to Drill, Well 1J-158L1 Revision No.O Saved: 16-Apr-07 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25. 005 (c)(9) An application for a Permit to Driil must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(~; Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit Yo Drill must be accompanied by each of the following items, except for an item already on Fle with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.06i (a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11.Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied 6y each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drifled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating dri0ing vessel, an analysis of seabed conditions as required by 20 AAC 25. 061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. Note: Previous operations are covered under the 1J-158 Application to Permit to Drill. ~ 1. Run and set Baker WindowMaster whipstock system, at window point of +/-7,449' MD / 3,250' TVD, the top of the B sand. 2. Mill 6-3/4" window. POOH. / 3. Pick up 6-3/4" drilling assembly with LWD and MWD and PWD. RIH. ~ 4. Drill to TD of D sand lateral at +/- 12,225 MD / 3,228' ND, as per directional plan. 5. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 6. PU and run 4-1/2" slotted liner. 7. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. POON. 10. POOH, laying down drill pipe as required. 1J-158L1 PERMITIT Page 5 of 6 ~ ~ ~ ~ Printed: 16 Apr-07 Q~~~ ~ Appl~n for Permit to Drill, Well 1J-158L1 Revision No.O Saved: 16-Apr-07 11. PU ESP completion with with backup gaslift as required and RIH to depth. Land tubing. Set BPV. 12. Nipple down BOPE, nipple up tree and test. Pull BPV. 13. Freeze protect well with diesel. 14. Set BPV and move rig off. 15. Rig up wire line unit. Pull BPV. 15. Circulate out weVl with diesel through the ESP 17. Set gas lift valves in mandrels. Operate well on gas lift until ESP facilities are ready. 18. Replace gas lift valves with blank dummy valves. 19. Place well on production with ESP. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Dri/l must be accompanied by each of the fol/owing items, except for an item a/ready on fi/e with the commission and identified in the application: (i4) a general desc~ iption of how the operator plans to dispose of drilling mud and cu(tings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings ~ generated will be disposed of either down a permitted annulus on iJ Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic 1J-158L1 PERMIT /T Page 6 of 6 (^~ ~ ~ ~ ~ ~ J~ ~ Printed: 16-Apr-07 t.~ ~~~ 1 1J-158 I.~Drillin~ Hazards ~.imma (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS} 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Mitigation Strateg Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud Pressure '~ weight. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out, backreaming Wellbore Collision with Moderate Adhere to Directional Program, Directional Existing wells Driller to update Traveling cylinder diagrams for every survey and monitor well to well proximities. 1J-158L1 Dnlling Hazards Summary n~~~~~~~ prepared by Dennis D. Hartwig ~, ~ 4/16/2007 9:31 AM S ~ ~ ~ ~ ConacoPh ~ [ I ~ ps Alaska ~ Plan: 1J-158 L1 (wp09) Sperry Drilling Services Proposal Report - Geographic 09 April, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-158 - Slot 1J-158 1J-158 L1 Local Coordinate Origin: Centered on Well Plan 1 J-158 - Slot 1J-158 Viewing Datum: D15 (40+81) @ 121.OOft (D15 (40+81)) '` TVDs to System: N / North Reference: True '~ Unit System: API - US Survey Feet H~4LL1E3URTC~N 3perry Drilling SBrvice~ O~~G~~AL ~ ~ Od 500 10d 7000 1500 r_-00 -------------- - ~ ________________ 10 3/4" ?000 ~ o ua0 --"----=--- ~`O L7:75/8"TOW(87449'MD.3250'ND:1025'FSL,2232'FEL-Sec34-T11N.F210E-' --- -'------------'------ 1865' FEL - Sec03-T10N-R10E 7533' FSL 12225' MD 3228' ND L1 BHL 8 p ° p _________ ~_______ - ______ ____________ , , : : ( ~ __ _______ __________ _________ ~ 3s0 ~ p,2400 i ~ O 0 ~ y i ~ ' i ~ °00 o --------- ---~o---o- ~ ----------`---------------------- i '------------------------- ---- ~ ----- ~ > _ _ ________'___ __ ~_ ______________ ___ ____ ________________________ __-~____~~______'_________________ O ~ a -a____o__'_'____$_~ ____ " '___'_ ~ ------------- ____ N____o_________ _4~I2'____-___ y 32D0 -------------- ---- _-~WSaI,~ ~__' ____________ t ~_______________________ • m --a°, ---- "'_ ~ ---- --`---- ---- ~ ' ~ '~ ~ i ' ~ _.iJ-158L1 (wp09) _____ ' I '_____ " '________________ _____ __ ____ o ° a o ° oi i iJ-758 (wp09) o ~~ 3600 7 5/8" TOW i ~ i i ~ i ~ ~ i i i i 4000 i i i i ~ i i i i ~ ~i ' i i i i ~ ~ 1 1 J-158 L2 (wp09) T2 i 1 J-158 L2 (wp09) TS i 1 I 1J-158 ~L2 (wp09) T# iJ-158 L2 (wp09) T70 ~~-~ 58 D-Toe (wp09) ~ 4400 ~ i iJ-158 L2 (wp09) T4 ~~'~58 L 2 (wp09) TB 1J-158 L2 (wp09) TB iJ-158 L2 (wp09) T11 1200 -800 -400 0 400 800 1200 1600 2000 2400 220~ ?2G0 3500 4000 4400 4800 5200 5600 6000 8400 6800 ~200 7600 8W0 Vertical Section at 180.OOd (1000 Win) ORIGINAL HALLIBU RTON QCt. KUpB~UIC RIVef Ufllt ~.L1-DE'CAILS: Plan IJ-I58 o~~ua.o .,w ca~..aa.. ~: 1 J Pad c~o ~~~~~~: st.oo ~~~~~ Well: P J-158 +N/-S +F/-W Nonhing Fasting -[a ~ Longitude Sbt Wellbore: Plan 1- L1 0.00 0.00 594561785 169869083 70°15'44686N ' 979W Plan: 1J-158L1 (wp REFERENCEINFORMATION Co-ortlinate (N/E) Reference: Well Plan 1J-158, True North 2000 Vertical (TVD) Reterence: Doyon 15 (40+87) ~ 121.OOft (DOyon 15 (40+81)) Measuretl Depth Reference: Doyon 15 (40*87) @ 121.OOft (Doyon 15 (40+81)) Calculation Method: Minimum Curvature 1750 1500 CASING DETA[LS 1250 TuD T V~SS MD Size Name 2151 J2 2030]2 3393.43 10-3/4 10 3/4" 3249.57 3128.57 7449.33 7-5/8 7 5/8" TOW 1000 3227.89 3I06.89 12225.88 4-1/2 4 1/2„ 750 0 0 c SOO N ~ o N N ~ , ~ ~ '~' ~ N o 2SO ~'a ~ ~ O ry 2j ~ - ~ p sa 10 3/4" 250 3~ ~ -250 1p-rd -500 7 5/8" TOW /95d -750 79pd 189d -I000 . ~j ------ - LI _ 7 5/S" TOW ~ 7449' MU, 3250' ND~ 1025' FSL, 2232' FEL - Sec34-TI I N-RlOE -1250 t80d -I500 PSd ..-1750 ~ o -2000 174d ~ U-liSl.2lwp09) ~ - - _ ~ 2250 170d + C-2500 ~ ~-2750 1J-158 L (wp09) 4 - - - - t ~-3000 I J-I ~8 LI (~~p09) i____ ~ -3250 175d 175d -3500 i l-i 5s ~_ h~poe~ ~---- -3750 -4000 177d UJ 58 L? (~~P09) 7- - - - - -4250 176d -45~ I J-158 L2 (ap09) ~ - - - -4750 -5000 I1-I ~8 L. (wp09) i - - - _ -5250 177d -5500 l l-t ss [? (wpo9) T - - - -5750 a v2^ } _ _ I J-I 58 D-Toe (~~p0 ' . _ _ _ _ _ _ _ _ _ _ Ll ~. BHL @, L225' MD, 3??8"Iti'D~. 1533' FSL, 18GS' FEL - Sec03-Tl ON-RlOE i 7 -6000 ~ M Azimuths to True North ~ Magnetic North: 23.80° -6250 IJ-158 LI (wp09 ) Magnetic Field Strength: 57608.3nT -6500 Dip AngIe:80.80° Date: 9/12/2006 Model: BGGM2006 -6750 -6000 -5750 -5500 -5250 -5000 -4750 -4500 -4250 -4000 -3750 -3500 3250 -3000 -2750 -2500 -2250 -2000 -1750 -1500 -1250 -1000 -750 -500 -250 0 250 500 750 1000 West(-)/East(+) (1000 fi/in) ...,~ v~~ft71lVf-lL ~ ~ 4/9/2007 4:02:11 PM Page 2 of 7 ~~~~~~~~ COMPASS 2003.11 Build 48 COf'lOCO~'ti~~l S Halliburton Company HALLIBURTON p Compass Proposal Report - Geographic ,q~~ ~p~rry Drilli~g ~ervices ~ ConacoPhil[ips Alaska Halliburton Company Compass Proposal Report - Geographic ~ HALLtBURT N Sperry Driliing Services ~ -- - . 7,424.15 ~ - 79.71 - _ - i~r. 188.79 - ,245.09 i - ,124.09 d~ tN .. _:,~% ' - ,i - -1,028.61 ~ - _ ~ - . -4,961.16 :.. _~_ _ _ ~ ~ „i~ 0.00 - ~ _ .00 = .00 i _ - - i 0.00 7,436.15 81.62 188.79 3,247.04 3,126.04 -1,040.31 -4,962.97 15.90 15.90 0.00 0.00 7,456.15 81.62 188.79 3,249.96 3,128.96 -1,059.87 -4,966.00 0.00 0.00 0.00 0.00 7,760.42 90.37 180.30 3,271.23 3,150.23 -1,361.88 -4,989.88 4.00 2.88 -2.79 -44.43 7,845.06 90.37 180.30 3,270.69 3,149.69 -1,446.51 -4,990.33 0.00 0.00 0.00 0.00 8,007.17 91.41 173.90 3,268.17 3,147.17 -1,608.31 -4,982.13 4.00 0.64 -3.95 -80J3 8,532.17 91.41 173.90 3,255.25 3,134.25 -2,130.18 -4,926.36 0.00 0.00 0.00 0.00 8,722.69 85.24 166.64 3,260.82 3,139.82 -2,317.66 -4,894.22 5.00 -3.24 -3.81 -130.41 8,810.81 85.24 166.64 3,268.14 3,147.14 -2,403.10 -4,873.93 0.00 0.00 0.00 0.00 9,001.33 92.50 171.20 3,271.89 3,150.89 -2,589.86 -4,837.35 4.50 3.81 2.40 32.23 9,101.33 92.50 171.20 3,267.53 3,146.53 -2,688.59 -4,822.07 0.00 0.00 0.00 0.00 9,163.39 91.88 171.20 3,265.16 3,144.16 -2,749.87 -4,812.58 1.00 -1.00 0.00 -179.85 9,413.38 91.88 171.20 3,256.96 3,135.96 -2,996.79 -4,774.35 0.00 0.00 0.00 0.00 9,611.71 90.90 175.04 3,252.16 3,131.16 -3,193.59 -4,750.61 2.00 -0.50 1.94 104.32 9,978.96 90.90 175.04 3,246.42 3,125.42 -3,559.42 -4,718.87 0.00 0.00 0.00 0.00 10,236.85 89.61 177.28 3,245.28 3,124.29 -3,816.71 -4,701.60 1.00 -0.50 0.87 119.90 10,551.38 89.61 177.28 3,247.43 3,126.43 -4,130.88 -4,686.66 0.00 0.00 0.00 0.00 10,693.89 88.52 176.36 3,249.76 3,128.76 -4,273.14 -4,678.76 1.00 -0.77 -0.64 -140.08 10,981.61 88.52 176.36 3,257.21 3,136.21 -4,560.19 -4,660.51 0.00 0.00 0.00 0.00 11,156.90 95.52 176.67 3,251.04 3,130.04 -4,734.94 -4,649.87 4.00 4.00 0.17 2.50 11,307.67 95.52 176.67 3,236.53 3,115.53 -4,884.75 -4,641.15 0.00 0.00 0.00 0.00 11,442.70 90.12 176.67 3,229.89 3,108.89 -5,019.35 -4,633.32 4.00 -4.00 0.00 179.99 11,642.70 90.12 176.67 3,229.47 3,108.47 -5,219.01 -4,621.70 0.00 0.00 0.00 0.00 11,706.49 90.76 176.69 3,228.98 3,107.98 -5,282.68 -4,618.01 1.00 1.00 0.03 1.74 11,910.07 90.76 176.69 3,226.29 3,105.29 -5,485.91 -4,606.25 0.00 0.00 0.00 0.00 12,043.79 89.43 176.82 3,226.07 3,105.07 -5,619.41 -4,598.68 1.00 -1.00 0.10 174.32 12,225.29 89.43 176.82 3,227.89 3,106.89 -5,800.62 -4,588.62 0.00 0.00 0.00 0.00 4/9/2007 4:02:11PM Page 3 of 7 COMPASS 2003.11 Build 48 Q~~G~~~OL ~ Conoco hillips Alaska Halliburton Company Compass Proposal Report - Geographic ~ HALLIBURTOlV 9perry Drilling ~ervices 1J-158 L1 (vw09} ~ 7,424.15 79.71 188.79 3,245.09 3124.09 -1,028.61 -4,961.16 5,944,799.58 553,706.37 0.00 1,028.61 L1: 7 518" TOW @ 7449' MD, 3250' ND: 1025' FSL, 2232' FEL - Sec34-T11 N-R10E - W Sak D- 7 5/8" TOW C 7,436.15 ~ 81.62 188.79 3,247.04 3126.04 -1,040.31 -4,962.97 5,944,787.87 553,704.65 15.90 1,Q40.31 7,456.15 81.62 188.79 3,249.96 3128.96 -1,059.87 -4,966.00 5,944,768.29 553,701.78 0.00 1,059.87 ~ 7,500.00 82.87 187.55 3,255.87 3134.87 -1,102.87 -4,972.17 5,944,725.24 553,695.94 4.00 1,102.87 7,600.00 85.74 184.75 3,265.79 3144.79 -1,201.79 -4,982.82 5,944,626.26 553,686.06 4.00 1,201.79 7,700.00 88.63 181.98 3,270.70 3149.70 -1,301.48 -4,988.68 5,944,526.54 553,680.98 4.00 1,301.48 7,760.42 90.37 180.30 3,271.23 3150.23 -1,361.88 -4,989.88 5,944,466.13 553,680.25 4.00 1,361.88 7,800.00 90.37 180.30 3,270.98 3149.98 -1,401.46 -4,990.09 5,944,426.56 553,680.35 0.00 1,401.46 7,845.06 90.37 180.30 3,270.69 3149.69 -1,446.51 -4,990.33 5,944,381.51 553,680.46 0.00 1,446.51 7,900.00 90.72 178.13 3,270.16 3149.16 -1,501.44 -4,989.57 5,944,326.59 553,681.64 4.00 1,501.44 8,000.00 91.36 174.18 3,268.34 3147.34 -1,601.18 -4,982.88 5,944,226.92 553,689.12 4.00 1,601.18 8,007.17 91.41 173.90 3,268.17 3147.17 -1,608.31 -4,982.13 5,944,219.79 553,689.92 4.00 1,608.31 8,100.00 91.41 173.90 3,265.88 3144.88 -1,700.59 -4,972.27 5,944,127.61 553,700.50 0.00 1,700.59 8,200.00 91.41 173.90 3,263.42 3142.42 -1,799.99 -4,961.65 5,944,028.30 553,711.89 0.00 1,799.99 8,300.00 91.41 173.90 3,260.96 3139.96 -1,899.39 -4,951.02 5,943,928.99 553,723.29 0.00 1,899.39 8,400.00 91.41 173.90 3,258.50 3137.50 -1,998.80 -4,940.40 5,943,829.68 553,734.68 0.00 1,998.80 8,500.00 91.41 173.90 3,256.04 3135.04 -2,098.20 -4,929.78 5,943,730.37 553,746.08 0.00 2,098.20 8,532.17 91.41 173.90 3,255.25 3134.25 -2,130.18 -4,926.36 5,943,698.42 553,749.75 0.00 2,130.18 1J-158 L2 (wp09) T2 8,600.00 8921 171.32 3,254.88 3133.88 -2,197.44 -4,917.64 5,943,631.25 553,758.99 5.00 2,197.44 8,700.00 85.97 167.51 3,259.09 3138.09 -2,295.62 -4,899.29 5,943,533.22 553,778.11 5.00 2,295.62 8,722.69 85.24 166.64 3,260.82 3139.82 -2,317.66 -4,894.22 5,943,511.21 553,783.34 5.01 2,317.66 8,800.00 85.24 166.64 3,267.24 3146.24 -2,392.62 -4,876.41 5,943,436.41 553,801.73 0.00 2,392.62 8,810.81 85.24 166.64 3,268.14 3147.14 -2,403.10 -4,873.93 5,943,425.95 553,804.30 0.00 2,403.10 8,900.00 88.64 168.77 3,272.90 3151.90 -2,490.11 -4,854.97 5,943,339.10 553,823.93 4.50 2,490.11 9,000.00 92.45 171.17 3,271.95 3150.95 -2,588.55 -4,837.56 5,943,240.81 553,842.11 4.50 2,588.55 9,001.33 92.50 171.20 3,271.89 3150.89 -2,589.86 -4,837.35 5,943,239.49 553,842.32 4.50 2,589.86 9,100.00 92.50 171.20 3,267.59 3146.59 -2,687.28 -4,822.27 5,943,142.21 553,858.16 0.00 2,687.28 9,101.33 92.50 171.20 3,267.53 3146.53 -2,688.59 -4,822.07 5,943,140.90 553,858.37 0.00 2,688.59 1J-158 L2 (wp09) T4 9,163.39 91.88 171.20 3,265.16 3144.16 -2,749.87 -4,812.58 5,943,079.70 553,868.34 1.00 2,749.87 9,200.00 91.88 171.20 3,263.96 3142.96 -2,786.03 -4,806.98 5,943,043.58 553,874.22 0.00 2,786.03 9,300.00 91.88 171.20 3,260.68 3139.68 -2,884.80 -4,791.69 5,942,944.95 553,890.28 0.00 2,884.80 9,400.00 91.88 171.20 3,257.40 3136.40 -2,983.57 -4,776.40 5,942,846.31 553,906.34 0.00 2,983.57 9,413.38 91.88 171.20 3,256.96 3135.96 -2,996.79 -4,774.35 5,942,833.11 553,908.49 0.00 2,996.79 1J-158 L2 (wp09) T5 9,500.00 91.45 172.88 3,254.44 3133.44 -3,082.53 -4,762.36 5,942,747.47 553,921.15 2.00 3,082.53 9,600.00 90.95 174.81 3,252.35 3131.35 -3,181.93 -4,751.64 5,942,648.17 553,932.64 2.00 3,181.93 9,611.71 90.90 175.04 3,252.16 3131.16 -3,193.59 -4,750.61 5,942,636.52 553,933.76 2.01 3,193.59 9,700.00 90.90 175.04 3,250.78 3129.78 -3,281.54 -4,742.98 5,942,548.64 553,942.08 0.00 3,281.54 9,800.00 90.90 175.04 3,249.22 3128.22 -3,381.15 -4,734.33 5,942,449.10 553,951.49 0.00 3,381.15 9,900.00 90.90 175.04 3,247.65 3126.65 -3,480.77 -4,725.69 5,942,349.57 553,960.91 0.00 3,480.77 9,978.96 90.90 175.04 3,246.42 3125.42 -3,559.42 -4,718.87 5,942,270.98 553,968.34 0.00 3,559.42 1J-158 L2 (wpd9) T6 10,000.00 90.79 175.22 3,246.11 3125.11 -3,580.39 -4,717.08 5,942,250.03 553,970.29 1.00 3,580.39 4/9/2007 4:02:11PM Page 4 of 7 COMPASS 2003.11 Build 48 ~./~~ ~~~~~~.~ ~ ~ ~ 1 J-15$ Li ~_~- 09 ~ ~~ ~~~~ ~ ~, _ ~~~ ~ . ~ - _ ~ ~ ~ - - , - _ ~ , .,~ ,~a ~ ~,~ 10,100.00 90.29 176.09 3,245.17 3124.17 -3,680.09 -4,709.51 5,942,150.40 553,978.64 1.00 3,680.09 10,200.00 89.79 176.96 3,245.09 3124.09 -3,779.91 -4,703.45 5,942,050.64 553,985.48 1.00 3,779.9T 10,236.85 89.61 177.28 3,245.28 3124.29 -3,816.71 -4,701.60 5,942,013.86 553,987.62 1.00 3,816.71 10,300.00 89.61 177.28 3,245.72 3124.72 -3,879.79 -4,698.60 5,941,950.81 553,991.11 0.00 3,879.79 10,400.00 89.61 177.28 3,246.40 3125.40 -3,979.67 -4,693.85 5,941,850.98 553,996.63 0.00 3,979.67 10,500.00 89.61 177.28 3,247.08 3126.08 -4,079.56 -4,689.10 5,941,751.14 554,002.16 0.00 4,079.56 10,551.38 89.61 177.28 3,247.43 3126.43 -4,130.88 -4,686.66 5,941,699.84 554,005.00 0.00 4,130.88 1J-158 L2 (wp09) T7 1Q600.00 89.24 176.97 3,247.92 3126.92 -4,179.43 -4,684.22 5,941,651.32 554,007.82 1.00 4,179.43 10,693.89 88.52 176.36 3,249.76 3128.76 -4,273.14 -4,678.76 5,941,557.66 554,014.01 1.00 4,273.14 10,700.00 88.52 176.36 3,249.92 3128.92 -4,279.24 -4,678.37 5,941,551.57 554,014.45 0.00 4,279.24 10,800.00 88.52 176.36 3,252.51 3131.51 -4,379.01 -4,672.03 5,941,451.86 554,021.56 0.00 4,379.01 10,900.00 88.52 176.36 3,255.10 3134.10 -4,478.77 -4,665.69 5,941,352.16 554,028.68 0.00 4,478.77 10,981.61 88.52 176.36 3,257.21 3136.21 -4,560.19 -4,660.51 5,941,270.79 554,034.49 0.00 4,560.19 1J-158 L2 (wp09) T8 11,000.00 89.25 176.39 3,257.57 3136.57 -4,578.54 -4,659.35 5,941,252.45 554,035.80 3.99 4,578.54 11,100.00 93.25 176.57 3,255.39 3134.39 -4,678.31 -4,653.22 5,941,152.75 554,042.71 4.00 4,678.31 11,156.90 95.52 176.67 3,251.04 3130.04 -4,734.94 -4,649.87 5,941,096.15 554,046.49 4.00 4,734.94 11,200.00 95.52 176.67 3,246.89 3125.89 -4,777.77 -4,647.38 5,941,053.35 554,049.32 0.00 4,777.77 11,300.00 95.52 176.67 3,237.27 3116.27 -4,877.13 -4,641.59 5,940,954.04 554,055.87 0.00 4,877.13 11,307.67 95.52 176.67 3,236.53 3115.53 -4,884.75 -4,641.15 5,940,946.42 554,056.38 0.00 4,884.75 11,400.00 91.83 176.67 3,230.61 3109.62 -4,976.72 -4,635.80 5,940,854.50 554,062.45 4.00 4,976.72 11,442.70 90.12 176.67 3,229.89 3108.89 -5,019.35 -4,633.32 5,940,811.90 554,065.26 4.00 5,019.35 11,500.00 90.12 176.67 3,229.77 3108.77 -5,076.55 -4,629.99 5,940,754.74 554,069.03 0.00 5,076.55 11,600.00 90.12 176.67 3,229.56 3108.56 -5,176.38 -4,624.18 5,940,654.97 554,075.62 0.00 5,176.38 11,642.70 90.12 176.67 3,229.47 3108.47 -5,219.01 -4,621.70 5,940,612.36 554,078.43 0.00 5,219.01 1J-158 L2 (wp09) T10 11,700.00 90.69 176.69 3,229.06 3108.06 -5,276.21 -4,618.38 5,940,555.19 554,082.19 1.00 5,276.21 11,706.49 90.76 176.69 3,228.98 3107.98 -5,282.68 -4,618.01 5,940,548.72 554,082.62 1.00 5,282.68 11,800.00 90:76 176.69 3,227.75 3106.75 -5,376.03 -4,612.61 5,940,455.43 554,088.74 0.00 5,376.03 11,900.00 90.76 176.69 3,226.42 3105.42 -5,475.86 -4,606.83 5,940,355.66 554,095.30 0.00 5,475.86 11,910.07 90.76 176.69 3,226.29 3105.29 -5,485.91 -4,606.25 5,940,345.61 554,095.96 0.00 5,485.91 1J-158 L2 (wp09j T11 12,000.00 89.86 176.78 3,225.80 3104.80 -5,575.69 -4,601.13 5,940,255.88 554,101.78 1.00 5,575.69 12,043.79 89.43 176.82 3,226.07 3105.07 -5,619.41 -4,598.68 5,940,212.19 554,104.56 1.00 5,619.41 12,100.00 89.43 176.82 3,226.64 3105.64 -5,675.53 -4,595.57 5,940,156.10 554,108.12 0.00 5,675.53 12,200.00 89.43 176.82 3,227.64 3106.64 -5,775.37 -4,590.02 5,940,056.31 554,114.44 0.00 5,775.37 12,225.29 89.43 176.82 3,227.89 3106.89 -5,800.62 -4,588.62 5,940,031.08 554,116.04 0.00 5,800.62 !1: BHL @ 12225' MD, 3228' ND: 1533' FSL, 1865' FEL - Sec83-T10N -R10E - 4 1/2" -1J-158 D-Toe (wp09) / ~' 4/9/2007 4:02:11PM Page 5 of 7 COMPASS 2003.11 Build 48 ~ ~ ~ ~ ~ ~~ ~ / Halliburton Company ALLIBU T0 ~OIlOC0~1l~~1~5 Compass Proposal Report - Geographic q~~ Sperry Driliing Services ~ ~ _ 1 J-158 L1 ~; = w~, ~ - - ~ ~ ~ ~,, ,~ 3,267.53 ~~ ~ ~F ~ , ~' 1J-158 L2 (wp09) T4 -2,688.59 -4,822.07 ~ _ _ ~ 5,943,140.90 553,858.37 - Point 3,246.42 1J-158 L2 (wp09) T6 -3,559.42 -4,718.87 5,942,270.98 553,968.34 - Point 3,257.21 1J-158 L2 (wp09) T8 -4,560.19 -4,660.51 5,941,270.79 554,034.49 - Point 3,247.43 1J-158 L2 (wp09) T7 -4,130.88 -4,686.66 5,941,699.84 554,005.00 - Point 3,229.47 1J-158 L2 (wp09) T10 -5,219.01 -4,621.70 5,940,612.36 554,078.43 - Point 3,256.96 1J-158 L2 (wp09) T5 -2,996.79 -4,774.35 5,942,833.11 553,908.49 - Point 3,255.25 1J-158 L2 (wp09) T2 -2,130.18 -4,926.36 5,943,698.42 553,749.75 - Point 3,226.29 1J-158 L2 (wp09) T11 -5,485.91 -4,606.25 5,940,345.61 554,095.96 - Point 3,227.89 1J-158 D-Toe (wp09) -5,800.62 -4,588.62 5,940,031.08 554,116.04 - Point - 4 ~~'~~? 3,393.43 2,151.72 10-3/4 13-1/2 7,424.17 3,245.10 7-5/8 9-7/8 12,225.28 3,227.89 4-1/2 6-3/4 4/9/2007 4:02:11PM Page 6 of 7 COMPASS 2003.11 Build 48 ~.,,,, ~ ~„., ~ ~~~~~~~~~~. ~~'' Halliburton Company HA,LLIBURTON ~OIIOCOP~'11~~Ip~S Compass Proposal Report - Geographic Sperry Driliing ~erviaes ~ ~ ° ~, ~~ ~" s - - ~r _ - ~ ~ , - _ - - ~ ~~, ~ _ _ _ , , _~ ~ _ ,...~~~ v , m ~,: __ _ ~_. _ - 1,672.09 47.14 277.00 1,529.10 61.26 -498.90 Pfrost 1,866.77 53.81 279.18 1,655.46 81.38 -645.42 T3 2,629.56 73.55 282.32 1,935.41 229.37 -1,333.95 K15 3,393.43 73.55 282.32 2,151.72 385.68 -2,049.68 Casing Pt 5,474.82 73.77 245.23 2,739.17 480.64 -4,000.31 Ugnu C 6,023.40 73.88 226.36 2,892.03 185.78 -4,434.06 Ugnu B 6,251.56 73.92 218.51 2,955.31 24.12 -4,581.85 Ugnu A 6,747.81 74.02 201.44 3,092.34 -387.53 -4,819.24 K 13 7,424.15 79.71 188.79 3,245.09 -1,028.61 -4,961.16 W Sak D 4/9/2007 4:02:11PM Page 7 of 7 COMPASS 2003.11 Buiid 48 Q~~~~~AL y' Halliburton Company HALLt~U T N ~OtlOCO~'1I~~1~JJS Compass Proposal Report - Geographic Alaska Sperry Drilling Servtces ~ ~ ~ • • ConocoPh i I I ~ ps Alaska Plan: 1J-158 L1 (wp09) Sperry Drilling Services Anticollision Summary 09 April, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-158 1J-158 L1 Local Coordinate Origin: Viewing Datum: NDs to System; North Reference: Unit System: Centered on Well Plan 1J-158 - Slot 1J-158 D15 (40+g1) @ 121.OOft (D15 (40+g1)) N True API - US Survey Feet H/~ILL~BiuRiTQN Sperry Drilling Service~ ~~I~1I~AL ! • ~ SURVEYPROGRAM Date: 2007-03-277'00:00:00 ValidatM: Yev Vcrsioo: Depth FromDcpth To San~er/Plae Twl JU.110 613.00 CB-G5'RO-S$ R13.110 712J.15 h1~4'D+IFR-.4K-CAZSC 712J.IC 1222J.75 1J-I58 Ll (N'p09) 1iN'D+IFR-AK-CAZSC ConocoPhillips Alaska, Inc. Engineering Calculation Me[hotl: Minimum Curvature Ertor Sys[em: ISCWSA Scan MethoA: 7rav. CylinAer North ErrorSuRace: EllipticalCOnic Warning Method: Rules Basetl From Colour To MD ~ ANTICOLLISION SETf1NGS I~rterpolation Method: MD Interval: 50Stations Depth Range From: 7424.75 To 12225.2870713613 Manimum Range:1419.1025005J5 Reference: Plan: iJ-158 L1 (wp09) ~ 180 180 Trnvelling Cylinder Azimuth (TFO+AZI) ~°~ vs Centre to Centre Separation ~200 fl/in~ NAD 27 ASP Zona 4: VJELL DETNLS; Vian 7J-158 Grountl Level: 81.00 •N/5 «E/.yy Northinp Easting latittuda Longitude Slot 0.00 0.00 5945868.71 558658.89 70°75'65.747N 149°3t'J2.833W 7J-158 REFERENCEINFORMATION Coortliiate (N/E) Reterence: Well Plan 1J-758 - Slot 1J-758, True North Vertical (ND) Reference: D75 (40.87) ~ 121.OOft (D75 (40+81~) Se<tion (VS) Reference: Slot - 7J-t58(O.OON, O.OOE) Measured Depth Reference: D15 (40«g~) ~~y~,00tt (D1 S(40+87)) Calculation Methotl: Minimum Curvature ~i,xur~woin u.,xurw~~r. ~s~ u~.sw~*s uiseut~ws~.e ~s~ ~:~e~n uiseu~m~n u~vuamaino ~a, ~:awsm~ ,~,ao.m~.,ws~ Tra.cllinq Cplindcr Nimuth (fFO+AZq ~°~ cs Cco1re ro Ccntrc Separafion ~3U ft/in~ QRIGINAL ConocoPhillips Alaska • ~ Halliburton Company Anticollision Report H~o-L~~c~uR-roiv Sperry Drilling Services Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refer Interpolation Method: MD Interval 25.OOft Error ModeL• ISCWSA Depth Range: 7,424.15 to 12,225.29ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,418.53ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma 40.00 813.00 1J-158 (wp09) (1J-158) CB-GYRO-SS Camera based gyro single shot 813.00 7,424.15 1J-158 (wp09) (1J-158) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC ~ 7,424.15 12,224.75 1J-158 L1 (wp09) (1J-158 L1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 4/9/2007 5:09:41PM Page 2 of 5 COMPASS 2003.11 Build 48 ~~~~I~AL ~ ConocoPhillips Alaska Halliburton Company Anticollision Report • LLt' URTOI\I ~perry Drilling 3ervioes 1J-102 - 1J-102 - 1J-102 Out of range 1J-102 - 1J-102 L1 - 1J-102 L1 Out of range 1J-102 - 1J-102 L2 - 1J-102 L2 Out of range 1J-102 - 1J-102 L2 PB2 - 1J-102 L2 P62 Out of range 1J-102 - 1J-102 PB1 - 1J-102 PB1 Out of range 1J-102 - 1J-102 PB2 - 1J-102 PB2 Out of range 1J-102 - 1J-102 PB3 - 1J-102 P63 Out of range 1J-109 - 1J-109 - 1J-109 Out of range 1J-109 - Plan 109a L1 - 1J-109a L1 (wp02) Out of range 1J-109 - Plan 1J-109a - 1J-109a (wp02) Out of range 1J-109 - Plan 1J-109a L2 - 1J-109a L2 (wp02) Out of range 1J-152 - 1J-152 - 1J-152 Out of range 1J-152 - 1J-152 L1 - 1J-152 L1 Out of range 1J-152 - 1J-152 L2 - 1J-152 L2 Out of range 1J-152 - 1J-152 P61 - 1J-152 PB1 Out of range 1J-152 - 1J-152 P62 - 1J-152 P62 Out of range 1J-154 - 1J-154 - 1J-154 Out of ~ange 1J-154 - 1J-154 L1 - 1J-154 L1 Out of range 1J-154 - 1J-154 L2 - 1J-154 L2 Out of range 1J-156 - 1J-156 - 1J-156 Out of range 1J-156 - 1J-156L1 - 1J-156L1 Out of range 1J-156 - 1J-156L1P61 - 1J-156L1PB1 Out of range 1J-156 - 1J-156L2 - 1J-156L2 Out of range 1J-159 - 1J-159 - 1J-159 Out of range 1J-159 - 1J-159 L1 - 1J-159 L1 Out of range 1J-159 - 1J-159 L1 PB1 - 1J-159 L1 PB1 Out of range 1J-159 - 1J-159 L1 PB2 - 1J-159 L1 P62 Out of range 1J-159 - 1J-159 L2 - 1J-159 L2 Out of range 1J-159 - 1J-159 P61 - 1J-159 PB1 Out of range 1J-170 - 1J-170 - 1J-170 Rig Surveys Out of range 1J-170 - 1J-170 L1 - 1J-170 L1 Rig Surveys Out of range 1J-170 - 1J-170 L2 - 1J-170 L2 Rig Surveys Out of range 1J-170 - 1J-170 PB1 - 1J-170 PB1 Out of range 1J-170 - 1J-170 PB2 - 1J-170 P62 Rig Surveys Out of range Plan 1J-107 - Plan 1J-107 - 1J-107 (wp03) Out of range Plan 1J-107 - Plan 1J-107 L1 - 1J-107 L1 (wp03) Out of range Plan 1J-107 - Plan 1J-107 L2 (wp03) - 1J-107 L2 1 Out of range Plan 1 J-158 - 1 J-158 - 1 J-158 (wp09) 7,425.00 7,425.00 0.00 0.60 -0.60 FAIL - No Errors Plan 1 J-162 - 1 J-162 - 1 J-162 (wp05) Out of range Plan 1J-162 - 1J-162 L1 - 1J-162 L1 (wp05) Out of range Plan 1J-162 - 1J-162 L2 - 1J-162 L2 (wp05) Out of range Plan 1J-173 Kuparuk - 1J-73 E Lateral - 1J-73 E L 8,342.01 7,199.97 1,180.12 133.28 1,046.85 Pass - Major Risk Plan 1J-173 Kuparuk - 1J-73 Kuparuk - 1J-73 W L 8,342.01 7,199.97 1,180.12 132.70 1,047.42 Pass - Major Risk Plan 1J-173 Kuparuk - 1J-73 Pilot - 1J-173 Pilot (~ 8,342.01 7,199.97 1,180.12 133.28 1,046.85 Pass - Major Risk Plan 1J-174 (Q1 Phase 2) - 1J-174 - 1J-174 (wp0: 11,382.78 7,999.98 682.31 157.60 524.71 Pass - Major Risk Plan 1J-174 (Q1 Phase 2) - 1J-174 L1 - 1J-174 L1 11,382.78 7,999.98 682.31 157.62 524.68 Pass - Major Risk Plan 1J-176 (Q2 Phase 2) - 1J-176 - 1J-176 (wp0; 12,221.63 8,275.00 593.50 150.96 442.54 Pass - Major Risk Plan 1J-176 (Q2 Phase 2) - 1J-176 L1 - 1J-176 L1 12,221.63 8,275.00 593.50 150.92 442.58 Pass - Major Risk Plan 1J-178 (Q3 Phase 2) - 1J-178 - 1J-178 (wp0: Out of range Plan 1J-178 (Q3 Phase 2) - 1J-178 L1 - 1J-178 L1 Out of range Ri : 1J-103 - 1J-103 - 1J-103 __ Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 4/9l2007 5:09:41PM Page 4 of 5 COMPASS 2003. 91 Build 48 ~~~~~~~L , • • / Halliburton Company HALLIBURTON C0110C0~'li~~IpS Anticollision Report ,q~S~ 9perry Drilling 8ervioe~ ~ ~=~ - - ---~_~~ _ ~~ : : - ~ ~ ~ - -- _ - _ -~ ~_ ~ Rig: 1J-103 - 1J-103 L1 - 1J-103 L1 Rig: 1 J-103 - 1 J-103 L2 - 1 J-103 L2 Rig: 1J-103 - 1J-103PB1 - 1J-103P61 Rig: 1J-103 - 1J-103P62 - 1J-103PB2 Rig: 1J-103 - 1J-103PB3 - 1J-103PB3 Rig: 1J-105 - 1J-105 - 1J-105 Rig: 1J-105 - 1J-105 - 1J-105 (wp05) Rig: 1 J-105 - 1 J-105 L1 - 1 J-105 L1 (wp05) Rig: 1J-105 - 1J-105 L2 - 1J-105 L2 (wp05) Rig:1J-160-1J-160-1J-160 7,433.14 7,950.00 1,1&4.37 Rig: 1J-160 - 1J-160 L1 - 1J-160 L1 7,432.41 7,950.00 1,184.13 Rig: 1J-160 - 1J-160 L1 PB1 - 1J-160 L1 (Drill Ou~ 7,437.08 7,950.00 1,184.85 Rig: 1J-160 - 1J-160 L1 P61 - 1J-160 L1 P61 7,432.41 7,950.00 1,184.13 Rig: 1J-160 - 1J-160 L2 - 1J-160 L2 7,432.41 7,950.00 1,184.13 Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 110.24 1,074.13 Pass - Major Risk 110.35 1,073.78 Pass - Major Risk 110.31 1,074.54 Pass - Major Risk 110.27 1,073.86 Pass - Major Risk 110.35 1,073.78 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min eilipse separation 4/9/2007 5:09:4?PM Page 5 of 5 COMPASS 2003.11 Build 48 $~ ~ ~ ~ ~ [~ A ~.. 0 ~ ~ O Insulated Conductor n Casing, 20", 94#, K55 x ~ ~ ~~ 34", 0.312" WT @ ~ +/- 80' MD D~ ~ ~ ~ . v 41 ~ A ~ A F v~ 'C ~ o C ~ ~ C n A '.Y ~t ~ ~ n r+ 4 w+ !n ~ 10-3/4", 45.5#, L-SQ BTC ~~ @ 3,393' MD / 2,152' TVD _/7 r~i 73.5 degrees TD 16" hole Top o~iFgnu C ~n, 5,415' MD /25734' TVA -~ (1) Gas Lift Mandrel, CAMCO 4-1/2" x 1" Model KMBG w/ dummy valve, Q< 69 deg Electric Submersible Pump, Centrilift 418 HP motoq with FC6000 wireline deployed pump. Bottom a1 7,350' MD, 3,230' TVD Wellhead / Tnbiug Head / Tree, 10-3/4" x ~ 4-'/z", 5,000 ksi Tubing String: 4-1/2", 12.6 #, L-80, IBTM, 520" OD Connections (1) 3.875" DB nipple set+/- 500' Top of Wes~ Sak D(a,) 7,449' NID / 3,250' TUD - --' 158 Ll "D" Sand Window ~ ~ @ 7,449' MD / 3,250' TVD ~ ~ 80 de~rees ~ ~ ~"D" Liner, 4-1/2", 11.6#, L80, BTCM ~ .`, ! Top of West Salc B' ~a7, o; 7?~~~~ ~ E~'4a2~ T~D -~ Seal bore and ZXP packer for B liner ~, q ~ ~ @ 7,549' MD, 3,265' TVD ~ ~ y o~ b~~ ~ . . 7-5/8", 29J#, L-S0, BTCM, Cs~ a ~o~' o ~ _ ~ . ~n 8.024' MD / 3,324' TVD ~ ^~' °~ ~~ @ 85 degrees 7D 9J/8" hole °. y w' ~ ~ . ~ . ~ B Sand Liner, 4-1/2", 11.6# L8Q BTCM r, ~ 1J-158 Ll: 6-3/4" "D" sand lateral TD 12,225' MD / 3,228' TVD . . Angle 89 degrees ======_°_°_°°° ~ 1J-I58: 63/4" B sand lateral TD 12,231' MD / 3,300' TVD ~ ~ Angle 89 de~rees ~ • TREiYSMIT~'AL LE'I'T;CR CHECKLIST WELL ~ANIE K/~~-(~ /-~ ~~~~ ~ PTD# Z-~ ~ ~ G ~~ :~ ~ Developmeat Service Eacploratory Stratigraphic Test Yo~e-Conventioaai Wett Circte Appropriate Letter / Paragraphs to be Included ia 'Transmittal Letter ' CE~CK i ADD-ONS ~ W~T I (OPTIONS) ; APPLIES I T'EXT FOR APPROVAL LETTER ; ~ MLiLTI LATERAL ~ The pettnit is for a new weilbore segmen[ of cxisting ~ ! ~ ~ well Kf'~G°~ ~.,L ` j~~ i i' ~ ~([f last two digits in I -, , ; . Pecrnit No. ~ 7- ~ AP[ No. 50- C'~ ~~ ~ ~ ~ C`~ , ~ ; AP[ number are ; ' ~'- .~- ~ , , betwecn 60-69) Production ~hould coretinue to 6e repoRed as a function of the ~ ~ ; origina! 4PI number stated above. ; ~ P[LOT HOLE i[n accordance with 20 AAC 2~.00~(~, a!! records, da.ta and Io~s ; i I ~ acquir~d for the pilot hoie must be cleacty differentiated in both ~ ~ i ; well name ( Pf~ and API aumber ~ ~ ' '(~a- - -_,) from records, data and logs ~ I i ~ acquired for we[I ~ __ , SPACING EXCEPTION DRY DCtCH SA.tiIPLE The permit is approved subject to full compliance with 20 AAC 2~A». Approval to perfocate and produce / in,,l'ect is contin~ent upon issuance of a conservation order approving a spacing exception. assumes the Iiabi[ity of any protest to the spacing exceptioa that may occur. f ~~11t dry ditch sample scts subrnitted to tt~e-~ommission must be ';in i no greater than 30' sarnple inrervals from betow che permafirost oc ; I from where samples are frst caught and 10' sample intervals j L through target zones. ; ~ ; ~ ~ Please note the following. specia! condition of this permit: j Non-Conventional ~ production or production testing of coal bed methane is not allowed ; i Wel1 for (~r ~e of we111 until after (Cornnan`r Name) has designed and i ~~mp(emented a water we!! testing program to provide baseline data ; ~ ; vn water uali and uanti (Cam q t3' q tY• ~y Name) must contact the i I ~ Commission to obtain advance approva! of such water well testing ~ pro~tram Rev: I !2jr06 C:` jody~transmittai_checklist ~ : ~ . . , . , . . ~.l., .. ~~fn _ . ,J>1,~.f,=.~.f!)!~n.?IwI,~~~it~J.,,~f), i,ia.~'~ , . ., . ., ~ , ., , ., .. .. . .. Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 Well Name: KUPARUK RIV U WSAK 1 J-158L1 _ Program DEV ___ ___ Well bore seg j~ PTD#:2070550 Company CONOCOPHILLIPS ALASKA INC Initial Classliype DEV f PEND GeoArea 890 .___ Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Pe[mikfee attached_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ , _ West Sak D Sand multilateral welt branch; fee waived per 20 AAC 25.005(e), _ _ . _ _ _ . _ . _ _ _ . . _ . 2 Leasenumberapprgpriate____________________ _______ Yes_ ____ Top_prodinteNalADL0025660;TDADL0025663_______________________ 3 Uniquewell_nameandnumber------__---_------,_-------------- Yes- ---------------------_---_----- ~ .. .............. -- -- - -- - 4 Well located in_a_defined_pool_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ Kuparuk River, West_Sak Oil Pool -490140,_ goyerned by_CO 406B_ _ _ _ _ 5 Well located p[oper distance from drilling unitboundary_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ CO 4066, Rule 3; no reskriction~ as to well &pacing except that no_pay shall be opened in a well clo&er _ _ 6 Well located p[oper distance from other wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ . , . than 500 feet So_a_n exte(nal property line W_here ownersh_ip_ or landownership changes_. _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ 7 Sufficient acreage ayailable in,drilling unit_ _ _ _ _ _ _ _ _ _ _ _ _ _ Y_es _ _ _ _ _ _ Well is more than_ 500 feel from an external ro,ert line. _ _ P p Y - 8 Ifdeviated,isweliboreplatincluded_________________ _____________.._ Yes_ __________________________ - - 9 Operator only aff_ected party_ _ _ . _ _ . _ _ _ . . _ _ _ _ _ . . _ Yes _ _ . . - - 10 Ope[atothas.appropriatebon~infarce----- --- ------- ----- Yes- -- --- - ----- -- - -- -------- -- ------ ---- - - - - - 11 Permit can be issued without conservation order Yes - Appr Date ~ 12 Permit_canbeissuedwithoutadministrative_approyal_________________________ Yes_ ________________________ ________________________,___ SFD 4/27/2007 13 Can permit be approved before 15-day wait Yes 14 Well located within area and_strata authorized by Injection 0[tler # (put_ 10# in_commentsj_ (For NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ . , . _ _ _ _ 15 Allwells_within114_milearea_ofreyiewidentified(Forservicewelionly)_______________ NA_ ____________________._._.._,._____._.,_ - -- - 16 Pre-produced injector, du[ation_of pre p[oduction less than. 3 months. (For service well only) _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - 17 Nonconyen. gas cgnfor_ms to A$31,05,030Q.1_.A),(~.2.A-D) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ . , _ . . _ _ _ Engineering 18 _C_onductorst[ing_provided _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA . _ _ _ _ _ C4ntluctorset_in 1J-158_(207-054). _ _ 19 Su_rface casingp_rotects all,known lJ$DWs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ AlI aquifers exempted, 40 CFR_147.102 (b~(3), _ . _ , . _ _ _ _ _ _ _ _ _ . . _ . . _ _ . . . . . . _ _ . _ _ 20 CMT_vol adequate_to circ_ul_ate_on conductor & surf csg _, _.. NA_ . __._. $urface casing set in 1J-158. 21 CMT_vol adequate_to tie-in_long string to.su[f csg _.__. NA_ _ ____ _ Production_casing set in_1J-148.. 22 CMT_will coyer all known.productive horizon_s_ _ _ _ _ _ _ _ No_ _ _ _ _ _ Slotted_liner completion planned_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 23 Casing desyns adequate foc C,_T, B &_permaf[ost_ . . _ _ NA _ . _ _ _ _ Mother,bo[e_ metdesign specificaitons, NA for slotted_liner, _ . _ _ _ _ 24 _A_dequate tankage_or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ Rig is_equipped with steel_pits. _No reserve_pit_planned. All waste to_approyed disposal_well(s)._ _ , 25 If.a_re-d(ill, has_a 1_0-403 for abandonment been approved _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ , . _ _ . _ _ _ 26 Atlequate wellbore separat_io_n_proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ . _ Proximiry analysis performed, Nearest seqment is mothet-bore 11_-_70'_tytl deepec_ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ 27 If dive[ter required, does it meet regu_lations_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ , _ BOP stack_will al[eady_be_in place, _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Appr Date 28 Drillin fluid ro ram schematic_& equip list adequate_ __ 9 P 8 Yes _ ___ _ Maximum expected formalion pressur_e 9,0 EMW, Planned mud wefyht8.9+ ppg__ __ _____________ _ TEM 4/30/2007 29 BOPEs,.do they meet_ regulation - - - Yes . . _ _ . . - . c~,(/1 30 _B_0_PE_press rating app[opriate; test to_(put psig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ MA$P calculated_at 11_73psi, 3K stack arrangement and BOP,test plann_ed, _ ~ 31 Choke_manifoldcomplieswlAPl_RP-53(May84)---- Yes- ---- --- ----------------- ---------------------------- ------------------ 32 Work will occut without operatio_n shutdown_ _ _ _ _ _ _ _ _ _ _ _ _ - Yes _ _ _ _ . _ _ . . . _ 33 IspresenceofH2Sgasprobable_ ______________ ___ _._____.____. No_. ____ H2Sisnpt.reportedinWS._Righassensors_andal_arms,____________________________., .. 34 Mechanical_condition of wells within AOR yerified (Fo[service well onlya _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA. _ _ _ _ . _ . _ _ Geology 35 Permit can be issued wlo hydrogen_ sulfide measutes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . _ _ _ _ _ H2S has notbeen encountered in W Sakwells drilled to the_ south from.1 J-Pad. 36 Data_p_resented on potential oyerpressure zones_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ . _ _ _ Expected res._pressure is ~8,5 to 9.0 ppg EMW; will be drilled with_oil-based mud, Mud weight will_be_ _ _ _ _ _ _ Appr Date 37 Seismic_analysis of shallow gas_zones_ _ _ _ _ _ _ _ NA_ _ _ . _ _ _ . adjusted as needed. _ _ _ _ . SFD 4/27/2007 38 Seabed condition suryey_(if off-sho[e) _._,___ NA- 39 Contact namelphone for weekly_progress repo[ts [exploratory only] _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ Geologic Engineering Public Date: Date Date West Sak D sand roducer. This is a well branch from a dual-horizontal roduction well. SFD p p Commissioner: Commissioner• Commissioner ~ C~~ ~~_~ ~ ~ i ~ Well History File APPENDIX Information of detailed nature that is not • parlicula~iy geRnane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to sim.plify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special efifort has been made to chronologically . organize this category of information. . ~ 17158L1o06142007SSN.txt Sperry-Sun Drillin9 Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu sep 06 09:52:54 2007 Reel Header Service name .............LISTPE ~ate . ...................07/09/06 Ori 9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Tape Header Service name .............LISTPE ~ate . ...................07/09/06 Origin ...................STs Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................5T5 LIS Physical EOF Comment Record TAPE HEADER -cuparuk -tiver unit west sak MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNE55: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ~ibrary. scientific Technical services writing ~ibrary. Scientific Technical Services 17-158~1 500292335660 ConocoPhillips Alaska znc. Sperry Drilling Services 06-SEP-07 MWD RUN 2 MWD RUN 4 MWD RUN 5 w-0005034555 W-0005034555 w-0005034555 B. HENNINGSE R. FRENCH R. FRENCH M. THORNTON M. THORNTON M. THORNTON MWD RUN 6 w-0005034555 B. HENNINGSE F. HERBERT 35 11N lOE 2055 2550 Page 1 ~ v~--OS<S ~ t SSl ~5 . ~ 17158L1o06142007SSN.txt ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 121.55 GROUND LEVEL: 81.00 # WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN} SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 3393.0 2ND STRING 6.750 7.625 7443.0 3RD STRING 47H STRING # REMARKS: ~ 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. AL~ VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS LATERAL WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 7443'MD/ 3250'ND, WITHIN THE RUN 2 INTERVAL OF 1J-158. THE WHIPSTOCK WAS SET, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 4. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,5,6 COMPRISED DIREC7IONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE-WHILE-DRILLING (PWD), AND GEO-PILOT ROTARY STEERABLE BHA (GP). 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1,2,4-6 REPRESENT WELL 1J-158 L1 WITH API#: 50-029-23356-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12261'MD/3236'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHAL~OW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). $ File Header Service name... .......STSLIB.001 Service Sub Level Name... Page 2 ! ~ 17158L1o06142007S5N.txt version Number. ........1.0.0 ~ate of Generation.... .07/09/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD ~epth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPM RPS RPD RPX ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 3371.0 3380.0 3380.0 3380.0 3380.0 3380.0 3405.5 STOP DEPTH 12212.0 12219.0 12219.0 12219.0 12219.0 12219.0 12261.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ BIT RUN NO MERGE TOP MERGE BASE 2 3371.0 7443.0 4 7443.5 7475.0 5 7475.0 11461.0 6 11461.0 12261.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~ing Direction .................DOwn optical log depth units...........Feet ~ata Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. . .. .. ..... ~atum specification Block sub-type...0 Name service order DEPT RPD MWD RPM MWD RPS MWD RPX MWD FET MWD GR MWD ROP MWD units size Nsam Rep Code offset FT 4 1 68 0 OHMM 4 1 68 4 OHMM 4 1 68 8 OHMM 4 1 68 12 OHMM 4 1 68 16 HOUR 4 1 68 20 API 4 1 68 24 FT/H 4 1 68 28 Page 3 channel 2 4 6 8 ! +~ 17158~1006142007SSN.txt First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3371 12261 7816 17781 3371 12261 RPD MwD OHMM 0.48 2000 42.8508 17679 3380 12219 RPM MwD OHMM 0.34 2000 40.9673 17679 3380 12219 RPS MwD OHMM 1.35 385.62 41.3304 17679 3380 12219 RPx MwD OHMM 2.5 1936.54 44.2347 17679 3380 12219 FET Mw~ HOUR 0.12 250.82 1.23221 17679 3380 12219 GR Mw~ API 21.11 132.79 64.5801 17683 3371 12212 ROP MwD FT/H 1.61 1535.71 265.878 17712 3405.5 12261 First rteading For Entire File..........3371 ~ast rteading For Entire File...........12261 File Trailer Service name... .......STSLI6.001 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/09/06 Maximum Physical rtecord..65535 File TyC~ e ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/09/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name,......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3371.0 7443.0 RPD 3380.0 7443.0 RPX 3380.0 7443.0 RPM 3380.0 7443.0 FET 3380.0 7443.0 RPS 3380.0 7443.0 RoP 3405.5 7443.0 $ # LOG HEADER DATA DATE LOGGED: O1-JUN-07 SOFTWARE SURFACE SOFTWA RE VERSION: Insite Page 4 i 1]158~100614200755N.txt DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7443.0 TOP LOG INTERVAL (FT): 3405.0 BOTTOM LOG INTERVAL (FT): 7443.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (5): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # # # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN~: EWR FREQUENCY (HZ): REMARKS: # Data Format Specification Record Data Record Type... ..........0 ~ata Specification Block Type.....0 Log~ing Direction .................DOwn optical log depth units...........Feet ~ata Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined ,4bsent value ......................-999 ~epth units. . .. .. ..... ~atum Specification Block sub-type...0 72.9 82.7 • TOOL NUMBER 053516 81390 9.875 3393.0 Native/spud Mud 9.10 58.0 9.5 200 4.4 2.000 72.0 1.280 116.6 3.000 72.0 2.400 72.0 -vame Service order units Size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 Page 5 i i 17158~1006142007S5N.txt GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3371 7443 5407 8145 3371 7443 RPD MWD020 OHMM 0.48 2000 16.2197 8127 3380 7443 RPM MWD020 OHMM 0.34 2000 13.872 8127 3380 7443 rtPS MWD020 OHMM 1.35 44.59 12.7189 8127 3380 7443 RPX MWD020 OHMM 2.5 1936.54 12.516 8127 3380 7443 FET MwD020 HOUR 0.15 95.53 0.999493 8127 3380 7443 GR MWD020 API 21.11 115.39 65.0305 8145 3371 7443 ROP MWD020 FT/H 7.47 1535.71 265.727 8076 3405.5 7443 First rteading For Entire File..........3371 ~ast Reading For Entire File...........7443 File Trailer Service name... .......STSLIB.002 Service Sub Level Name... version Number.. ........1.0.0 Date of Generation.......07/09/06 Maximum Physical Record..65535 File Ty[~ e ................LO NeXt Flie Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 Service Sub Level Name... version Number.. ........1.0.0 Date of Generation.......07/09/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 7443.5 7475.0 $ # LOG HEADER DATA DATE LOGGED: 10-JUN-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7475.0 Page 6 ~ ~ . 17158~10061420075SN.txt TOP LOG INTERVAL (FT): 7443.0 BOTTOM LOG INTERVAL (FT): 7475.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .O MAXIMUM ANGLE: ,Q # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7443.0 # BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD vISCOSITY (S): 56.0 MUD PH: ,Q MUD CHLORIDES (PPM): O FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 95.1 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ..........0 ~ata Specification Block Type.....0 Log~ing Direction .................DOwn optical log depth units...........Feet ~ata rteference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. . .. .. ..... Datum specification Block sub-type...0 Name service order units size -vsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 7443.5 7475 7459.25 64 7443.5 7475 ROP MwD040 FT/H 2.04 49.99 15.7903 64 7443.5 7475 Page 7 ~ 17158L10061420075SN.txt First Reading For Entire File..........7443.5 ~ast Reading For Entire File...........7475 File Trailer Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/09/06 Maximum Physical rtecord..65535 File TyC~ e ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/09/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.003 comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 7443.5 FET 7443.5 RPX 7443.5 RPM 7443.5 RPD 7443.5 RPS 7443.5 RoP 7475.5 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 11412.0 11419.0 11419.0 11419.0 11419.0 11419.0 11461.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 Page 8 ~ header data for each bit run in separate files. 5 .5000 13-7uN-07 Insite 72.13 Memory 11461.0 7475.0 11461.0 82.8 96.0 TOOL NUMBER 64004 159439 • # # # # # 17158L1o06142007S5N.txt $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7443.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (5): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT ~EMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: # Data Format Specification Record Data Record Type... ..........0 ~ata Specification Block Type.....0 Log~ing Direction .................DOwn optical log depth units...........Feet ~ata Reference Point ..............undefined Frame Spacing....... ............60 .1~N Max frames per record .............undefined absent value ......................-999 ~epth units. . .. .. ..... Datum specification Block sub-type...0 Mineral 8.40 56.0 .0 22000 .0 .000 .000 .000 .000 Name service order units size Nsam Rep Code offset Channel . oil Base .0 110.0 .0 .0 DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7443.5 11461 9452.25 8036 7443.5 11461 RPD MWD050 OHMM 9.49 196.46 63.6097 7952 7443.5 11419 RPM MWD050 OHMM 8.75 220.74 61.3871 7952 7443.5 11419 RPS MWD050 OHMM 8.57 385.62 63.3937 7952 7443.5 11419 ttPx MWDOSO OHMM 8.36 1711.55 69.9612 7952 7443.5 11419 FET MwD050 HOUR 0.12 250.82 1.33925 7952 7443.5 11419 GR -wwD050 API 39.26 132.79 64.6707 7938 7443.5 11412 Page 9 • ~ 17158L1o06142007SSN.txt ROP MwD050 FT/H 1.61 925.34 261.113 7972 First Reading For Entire File..........7443.5 ~ast Reading For Entire File...........11461 File Trailer Service name... .......STSL2B.004 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/09/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/09/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11412.5 12212.0 RPx 11419.5 12219.0 RPD 11419.5 12219.0 FET 11419.5 12219.0 RPM 11419.5 12219.0 RPS 11419.5 12219.0 ROP 11461.5 12261.0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWA RE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEE D (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) Page 10 7475.5 11461 header data for each bit run in separate files. 6 .5000 14-JUN-07 Insite 72.13 Memory 12261.0 11461.0 12261.0 88.1 90.9 • ~ 17158~1006142007SSN.txt VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 64004 EWR4 Electromag rtesis. 4 159439 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7443.0 # BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 56.0 MUD PH: ,Q MUD CHLORIDES (PPM): 20000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 108.9 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: # Data Format specification rtecord Data Record Type... .. .......0 Data Specification Block Type.....0 Log~ing Direction .................Down opt~cal log depth units...........Feet ~ata Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined ,4bsent value ......................-999 Depth Units. . .. .. ..... ~atum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11412.5 12261 11836.8 1698 11412.5 12261 RPD MWD060 OHMM 45.15 108.09 74.948 1600 11419.5 12219 RPM MWD060 OHMM 44.63 118.49 77.1085 1600 11419.5 12219 RPS MWD060 OHMM 41.61 130.48 77.0042 1600 11419.5 12219 Page 11 y • ~ 17158~100614200755N.txt RPx MWD060 OHMM 37.78 164.25 77.4852 1600 11419.5 12219 FET Mw~060 HOUR 0.12 31.27 1.88231 1600 11419.5 12219 GR MwD060 API 41.23 90.32 61.8376 1600 11412.5 12212 RoP Mw~060 FT/H 18.03 393.15 300.39 1600 11461.5 12261 First Reading For Entire File..........11412.5 ~ast Reading For Entire File...........12261 File Trailer Service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/09/06 Maximum Physical Record..65535 File Ty e ................LO Next Fi~e Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/09/06 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date . ...................07/09/06 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File Scientific Technical Services scientific Technical services Page 12